Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
205-086
7. 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: PBU 15-31B Mill CIBPs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-086 50-029-22285-02-00 12210 Conductor Surface Intermediate Liner Liner 8801 75 3488 8921 1011 2872 12173 20" 13-3/8" 9-5/8" 7" 2-3/8" 8806 36 - 111 35 - 3523 32 - 8953 8651 - 9663 9338 - 12210 36 - 111 35 - 3523 32 - 8324 8149 - 8629 8511 - 8802 12173 470 2260 4760 5410 11780 none 1490 5020 6870 7240 11200 10180 - 12170 4-1/2" 12.6# L-80 31 - 9663 8803 - 8806 Structural 4-1/2" Baker SABL-3 , 9054 , 8380 No SSSV (TRDP locked out 2/24/10) 9054 8380 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com 907.564.5280 PRUDHOE BAY, PRUDHOE OIL 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: ADL 0028307 31 - 8629 174 845 26224 25368 5 38 0 0 354 342 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 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 By Grace Christianson at 9:30 am, Jan 11, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.01.10 15:49:27 - 09'00' Bo York (1248) RBDMS JSB 011124 WCB 2024-06-25 DSR-1/26/24 ACTIVITYDATE SUMMARY 12/14/2023 LRS CTU #1 w/1.5" Blue Coil. Job Objective: Mill 3 CIBPs Standby for snow removal, MIRU CTU M/U YJ 1.69" milling assembly w/1.78" burnshoe. RIH, Start milling CIBP at 10,220' ***Continued to WSR on 12/15/23*** 12/14/2023 Assist Coil Tubing. LRS Unit 76 Heat 225 bbls 1% KCL upright tank of to over 100*F. 12/15/2023 LRS CTU #1 w/1.5" Blue Coil. Job Objective: Mill 3 CIBPs Continue milling CIBP at 10,220'. Mill plug, push down to plug at 11,115'. Chase gel sweep out of liner. POOH and inspected tools, found plug core lodged in burnshoe. Change burn shoe and resume milling CIBP at 11,113', mill through plug and push down to third plug at 11,840', but could not get through. POOH and recovered some plug debris but no core, burn shoe had heavy wear. Make up new burn shoe and RIH. Tag 3rd plug, mill for 3 hours with no stalls. POOH recovered core from plug #2. Make up new 1.8" burnshoe RIH ***Continued to WSR on 12/16/23*** 12/16/2023 LRS CTU #1 w/1.5" Blue Coil. Job Objective: Mill 3 CIBPs Continue RIH w/1.8" burnshoe to mill plug #3. Milled plug, push to 11936, attempted to work past and pulled heavy after 3 stalls. unable to get jar hits, FP CT and surface lines to work pipe. Pop free 17k over. POOH to change out jars and swap burnshoe for mill. Make up junk mill and RIH. Tagged patch while RIH and motor got stuck into a stall, established circulation after several attempts but circ pressure was lower than normal, POOH to inspect motor. Make up new motor and RIH and resume milling plug at 11,933' work plug to 12,170.39' (12173' w/correction). POOH cap well with 8bbls diesel, turn well over to ops to POP. RDMO. ***Job Complete*** 12/18/2023 T/I/O = 450/1220/110. Temp = 80*. WHP's (Eval glaciation in cellar). No AL. Cellar is full of ice, no bubbling seen. 0% LEL's. Placed heater in wellhouse. Got cellar fluid sample. 16:30 Daily Report of Well Operations PBU 15-31B gg Change burn shoe and resume milling CIBP at 11,113', mill through plug and pushgg down to third plug at 11,840', but could not get through. j Continue milling CIBP at 10,220'. Mill plug, push down to plug at 11,115'. y Tag 3rd plug, mill for 3 hours with no stalls. POOH Job Objective: Mill 3 CIBPs The final CIBP to be milled is correctly shown on the WBS below. -WCB j Continue RIH w/1.8" burnshoe to mill plug #3. Milled plug, push to 11936, attemptedgg to work past and pulled heavy after 3 stalls. unable to get jar hits, FP CT and surfaceygj lines to work pipe. Pop free 17k over. POOH to change out jars and swap burnshoegj for mill. Make up junk mill and RIH. Tagged patch while RIH and motor got stuckjgg g into a stall, established circulation after several attempts but circ pressure was lower than normal, POOH to inspect motor. Make up new motor and RIH and resume milling plug at 11,933' work plug to 12,170.39' (12173' w/correction). POOH STATE OF ALASKA SLASKA OIL AND GAS CONSERVATION COMMI N ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations Q Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:5e t e//y, I}9" 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 205-086 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory El AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22285-02-00 7. Property Designation(Lease Number): ADL 0028307 8. Well Name and Number: PBU 15-31B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL I 11.Present Well Condition Summary: O Total Depth: measured 12210 feet Plugs measured See Attachment feet SEP true vertical 8801 feet Junk i 0 UJ measured feet Effective Depth: measured 11115 feet Packer measured 9054 feet j�('`�/ CCtrue vertical 8824 feet Packer true vertical 8379.68 feet ?-1 c A Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 75 20"91.5#H-40 36-111 36-111 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 8920 9-5/8"47#NT8OS 32-8953 32-8324 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10230-10255 feet 10340-10450 feet 10490-10580 feet 10650-10840 feet 11230-11280 feet 11320-11460 feet 11720-11770 feet 11890-12170 feet True vertical depth: 8817-8823 feet feet 8838-8840 feet 8839-8842 feet 8843-8841 feet 8823-8826 feet 8827-8835 feet 8821-8815 feet 8808-8806 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 31 -9663 31-8628 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"Camco TRDP-4A SSV 2078 2078 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: { a` SCANNED FEB � �0 17, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 287 27415 13 900 354 Subsequent to operation: 2 26553 0 850 334 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature A Phone +1 907 564 4424 Date 9/12/16 Form 10-404 Revised 5/2015 VTL. 412-471.f, RBDMS t,v SEP 1 3 2016 Submit Original Only • • Plugs Attachment PBU 15-31B SW Name Date MD Description 15-31 B 08/14/2016 11115 2-3/8"WFD CIBP 15-31B 09/14/2010 11840 2-3/8" CIBP • a, Q o0 0 0 0 s 0 � � IAn co c) N C N 't I� U o 0 0 0 0 0 0 i 0) IC) N N- O co ct O CO N N m �- M Lo Co I. r CO O M CO CO N N N N O N LO co Co coco c') cc cc cc cc H 0) co M co <n M 00 op N N CD N CO c- U) CT CO co M 00 0) 0) (.) o W r Cr) CO M M O CO CV CO LO CO CO c)) Cr) •_ a0 G O Lo a0 c O CC) o,o 01 ' W4kcco00OZ ~ N � •N N 10 CO co • *k f O) CO CO C.0 (NJ M COM CO© _ M O N r L +' M O N Cr)L0 10 O N N M C I,- CO V 0) CD 00 Co a) co co LU Lt 1- 0)0 CsO 0 H W Uw co QQ � C� O O W w CC C D Z ZWWUJ O > > Z Z D C.) GO U) Z J J H • e Packers and SSV's Attachment PBU 15-31B SW Name Type MD TVD Depscription 15-31B SSSV 2077.65 2077.61 4-1/2" Camco TRDP-4A SSV 15-31B PACKER 8659.19 8153.12 7" Baker H-Isolation Liner Packer 15-31B TBG PACKER 9054.22 8379.68 4-1/2" Baker SABL-3 Packer .. • • $ / co C //-J c") U) p 2\ N- k u aI G _1 ° O E p < k2 \ E ° k � / / - 7 < > k \ / c 7 Cr) 0 : c ± 0 c ® 0 / & a 2c / 0 / R / f t / co CD _l / ® / d < 8 mm 0 H > / / 2 CC _1 w / 2 ® A q i $ E Cr)CO I / k / / / $ U CO O C I E / \ E E C mo = w E I- LR ±_ I I m » 0. / 2 \ J / cn ƒ / i \ 8 g / / - R 13 � f O \ U $ _ O N \ _ - Q 5 CI \ H E G r m O O s z G 6 « & E R ") ciI ƒ p & ƒ O JI �� % „ I - CO (13 + \ - 2 A N. 2 ® R O o # o - o t 0 # 7 W 2 8 o_U 0- t � : � f ct < © 2 J < � N � / -- 0 � < \ / ƒ / / � u � 2 ® 4, U) < E a � � Ce fk / / / < / \ / / 1 / / / / / >. < < EOE / R2 \ cckE / \ / < m \ U ± p f / / � f / > g / / ƒ / / a5 % - 1 / k / O - / \ / CO COC T 0 / / OQI2 - \ / / / / ƒ � _� / a) 0 fCIONY ° Em00 = a \ / » _ / _ W I ' k Y 2 EEE \ f 0- S ƒ § _2 E / � Z % / / �/ ƒ 2 \ \ \ / D f / \ / 0 \ - 2 0 - u = L _ 2 r - - r o 0 4 a) t 2 0 : m I I m O c t & t & O I i 5 w R \ o o e o H ,- co \ \ / d 5 + b _® » ^ ¥ N- & O + < TREE= 4-118"CNV FLS VVE LI-EAD= CM/ S NOTES: WELL ANGLE>70°@ 9636'. rACTUATOR= BAKER C 1 5-31 B MAX DLS:50.9°@ 9672'. OKB.ELEV= 64.6' BF. ELEV= KOP= 554(Y ��- 2078' -4-1/2"CAMCO TRDP-4A,SSSV NP,D=3.812" Max Angle= 100°@ 11038' { '/, LOCK®OUT(02/24/10) Datum M)= N/A Datum TVD= 8800'SS l I 2926' H4-1/2"X 3-1/2"XO,D=2.990" 4-1/2"TBG,12.6#,L-80,.0152 bpf,0=3.958" - 2926' GAS LIFT MANDRELS 13-3/8"CSG,68#,L-80,D=12A15" - 3540' , ST M) TVD DEV TY FE VLV LATCH PORT DATE — 1 3189 3188 2 140114G-2 DMY RK 0 02/26/10 3-1/2"BKR KB(CR)PATCH, "I 8305'-8335' 2 5498 5494 9 N?iG-2 DMY RK 0 02/26/10 D=1.830"(09/18/10) 3 6971 6872 29 MNG-2 DMY RK 0 08/29/03 4 8378 7984 50 MM3-2 DMY RK 0 08/29/03 TOP OF 7"LNR 8651" Li 5 8503 8062 53 IMIG-2 DMY RK 0 08/29/03 9-5/8"CSG,47#,NT-80S,D=8.681" H 89$2' ' I 1( 9031' .H3-1/2"PKR SWS NP,D=2.813" 3-1/2"TBG,9.2#,L-80,IDS,.0087 bpf,D=2.990" H 9050' I-- ----- 9050' H3-1/2"X 4-1/2"XO,D=3.00" c 909-11-17"X 4-1/2"BKR S-3 PKR,D=1930" Minimum ID =1.830" @ 8336' 9057' H4-1/2"x 3-1/2"x0,D=3.00" BOTTOM OF 3-1/2" KB PATCH ' 9071' H3-1/2"PKR SWS NP,D=2.813"j EST TOP OF CEMENT -I 9339' I • -I 9338' H 3'PB BKR DEPLOY SLV,D=2.250 •4 i !i TOP OF 2-3,8"LNR H 9344' • 9344' 1-2-314"X 2-3/8"X0,D=1.920'1 ♦ Pi ► ♦• TBG PUNCH(06/06/02) - 9502'-9507' s` m�♦ WFD WHPSTOCK(07/06/05) --I 9863' ♦•4♦ •/j♦ r ♦•►♦ •1�♦ f MLLOUT WNDOW(15-318) 9663'-9668' RA TAG -1 9668' ��►♦• ♦♦• I 3-1/2"BKR CEP(SET 6/9/05) H 9765'CTMD} ♦• ,�\�w ♦♦i"♦'♦"♦'• PERFORATION SUMMARY ♦'!♦!♦!♦!♦i', • REF LOG: n? ♦� % 11115'CTM •-?.??"WFD CEP(08/14/16) ANGLE AT TOP PERF: 74°@ 10230' •♦e !♦ Note:Refer to Roduction DB for historical perf data ♦•'= =� ♦ I 11840' H 1.71"CEP(09/14/10) • SIZE SPF INTERVAL Opn/Sqz SHOT SOZ a a• I 12174' IHPBTD 1 1-9116" 6 10230-10255 0 09/14/10 •4 !4v 'r,• 1-9116" 6 10340-10450 O 07/16/05 t ;to. 7 1-9/16" 6 10490- 10580 0 07/16/05 1 ..11. 1-9/16" 6 10650-10840 0 07/16/05 .• _ •1. 1-9/16" 6 11230- 11280 C 07/16/05 • 1 1-9/16" 6 11320-11460 C 07/16/05 •• o• ''• 41,11,14% qr 1-9/16" 6 11720-11770 C 07/16/05 •• l• 1-9/16" 6 11890-12170 C 07/16/05 •I 0. tA I. 4, — I6. 2-3/8"LNR,4.7#,L-80,STL, 12210' " ► .0039 bpf,ID=1.920' 7"LNR,27#,NT-80,NSCC.0383 bpf,D=6.276" -I 11084' 4-1/2"SLTD LNR, 12.63#,L-80, - 11728' FL4S, 0152 bpf,D=3.958" DATE REV BY COPIIbEN S DATE REV BY COMMENTS PRUDHOE BAY INT 10/01/92 ORIGINAL COMPLETION 09/21/10 CJS/PJC CEP/FE FS(09/14/10) WELL: 15-31B 09/01/93 LAST WORKOVER 08/26/14 DLYJM3 TREE 0l0(08/25/14) FERMI No:"2050860 06/16/02 JDM/KK CTD SDTRCK(15-31A) 08/14/16 LLVTLH CEP SET AR No: 50-029-22285-02 07/17/05 NORDIC 1 CTD SDTRCK(15-31B) SEC 22,T11 N,R14E, 1937'FM.&1438'FWL 03/10/10 ?/PJC HOLD OPEN SLV/GLV(02/26/10) 09/21/10 SPB/PJC SET KB PATCH(09/18/10) - BP Exploration(Alaska) • 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. Q c~ - ~ ~ ~Q Well History File Identifier Organizing (done> ^ Two-sided Ill II'III (I III lI Ill ^ Rescan Needed III IIlIII II II III III RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ~skettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ` ~ /s/ Project Proofing III IIIIIIIIIII II III BY: Maria Date: ~' /s/ Scanning Preparation ~ x 30 = ~ + ~ cam-. =TOTAL PAGES ~~ (Count does not include cover sheet) ~ BY: Maria Date: ~ /s/ Production Scanning III IIIIII IIIII II III Stage 1 Page Count from Scanned File: ~~3 (Count does include cover sheet) Page Count Matches Number in Scann'ng Preparation: _~YES NO BY: Maria Date: ~ ~ ~, q 0 7 /sl Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II'I II I II II I I III ReScanned III II'III IIIII II Ill BY: Maria Date: /s/ Comments about this file: Quality Checked Ill II~III Ill IIII III 10/6/2005 Well History File Cover P~ge.doc Scbin~berger Alaska Daia 8 Consulting Services 2525 GamMll Street, Suae 000 Anchorage, AK 99503-2838 ATTN: Beth Well Job M Log Description Date BL 03-37 09AKA0188 OH MWDA.WD EDIT - 1 02/14/10 2 1 07-238 09AKA0078 OH MWD/LWD EDIT 01/10/10 2 1 V-123 04-42 06-12A X-04 BBKA-00002 B14B-00099 AP3O-00081 BBSK-00012 CH EDIT PDC SCM - INJECTION PROFILE PRODUCTION PROFILE - LDL - 01/15/10 03/23/10 03/21/10 -03/14/10 1 1 1 1 1 i 1 03-28 BBRH-00017 PRODUCTION LOG - 03/19/10 Y 1 14-11A B3SG-00050 PERF RECORD & FL G BHP /20/10 1 1 15-31B 03-10 14-07 03-11 12-26 P2-22 P2-22 03-28 AP3O-00082 89RH-00018 B748-00098 89RH-00019 ANHY-00121 BBSK-00011 BBSK-00011 89RH-00017 LDL - INJEC ION PROFlLE PERF RECORD & FLOWING BHP INJECTION PROFILE - PRODUCTION PROFILE - USI7 CORROSION DATA - USi7 CEMENT DATA CBL - j ~ 8 03M2/10 03/21/10 03/22/10 .03/22/10 - 03/16/10 03/11/10 03/11/10 03/19/10 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 15-30A 85JN-00045 SCMT ~ - - 03/22/10 1 1 MPS-08 BBUO-00009 USIT - 03/12/10 1 1 PLEACF Ar:KN[1Wt FIIr:C oer •enar ov e~r_u~u r_ w.,n o~~„e.,,.,.. ....~ ......., -..,.. -... BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-i 900 E. Benson Blvd. 03/25/10 ~~~~ 4.. N0.5461 Company: State of Alaska /~ (_~ [ } ~ ~j ~ fl a ~~ Alaska Oil & Gas Cons Comm !-1 !~ I~\ e., 1J Attn: Christine Mahnken 333 West 7th Ave, Suhe 100 Anchorage, AK 99501 ~~F,.~ ~^+~,.-.,., a _. -,_ ° Color CD rgt~,r"n^. `M Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchrorage, AK 99503-2838 ~ (~ 8 `~ (J ~ f l NOT OPERABLE: 15-31B (PTD #2060) Secured post failing MITIA • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, March 05, 2010 9:03 PM ~~~~3~ ~~'° To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Sinyangwe, Nathan Cc: Janowski, Carrie; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: 15-31 B (PTD #2050860) Secured post failing MITIA Attachments: 15-31 B TIO Plot.doc ,~ All, Producer 15-31 B (PTD #2050860) failed an MITIA on 03/01/10 after the gas lift valves were dummied off. The well was secured with a downhole plug followed by a passing - x verifying the plug is holding on 03/05/10. The well has been reclassified as Not Operable and will remain shut-in until repaired. Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, February 14, 2010 8:53 PM ~~'~~~~ I~iPr? ;~ ~ ~~~ To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; GPB, Area Mgr Central (GCl/3/F53); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Sinyangwe, Nathan Cc: Williams, Carrie; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 15-316 (PTD #2050860) Sustained Casing Pressure due to TxIA Comm All, Well 15-316 (PTD #2050860) has confirmed sustained IA casing pressure due to TxIA communication. The wellhead pressures were tubing/IA/OA equal to 2450/2150/0 on 2/11/10. A TIFL failed on 2/13/10 confirming TxIA communication. The well has been reclassified as Under Evaluation and may remain online while work is conducted to attempt to restore integrity. The plan forward is to: 1. DHD: TIFL -FAILED 2. Slickline: Set dummy gas lift valves, MITIA to 3000 psi A wellbore schematic and TIO plot have been included for reference. «15-31 B TIO Plot.doc» Please let us know if there are any questions. Thank you, 3/8/2010 NOT OPERABLE: 15-31 B (PTD #2060) Secured post failing MITIA • Page 2 of 2 Anna ~u6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: (907) 659-5100 x1154 3/8/2010 PBU 15-31 B PTD #2050860 3/5/2010 TIO Pressures Plot UNDER EVALUATION: 15-31~TD #2050860) Sustained Casing Pres~e due to TxI... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] j~ Z.~~(p~io Sent: Sunday, February 14, 2010 8:53 PM "~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 QS Ops Lead; GPB, FS3 DS Operators; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Sinyangwe, Nathan Cc: Williams, Carrie; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 15-31 B (PTD #2050860) Sustained Casing Pressure due to TxIA Comm Attachments: 15-31 B.pdf; 15-31 B TIO Plot.doc All, Well 15-31 B (PTD #2050860) has confirmed sustained IA casing pressure due to TxIA communication. The wellhead pressures were tubing/IA/OA equal to 2450/2150/0 on 2/11/10. A TIFL' fa~.d on 2/13/10 confirming TxIA communication. The well has been reclassified as Under Evaluation and may remain online while work is conducted to attempt to restore integrity. The plan forward is to: 1. DHD: TIFL -FAILED 2. Slickline: Set dummy gas lift valves, MITIA to 3000 psi A wellbore schematic and TIO plot have been included for reference. «15-31 B.pdf» «15-31 B TIO Plot.doc» Please let us know if there are any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) ~~~} ~~~ 20~I~ Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 2/16/2010 PBU 15-31 B PTD 2050860 2/14/2010 TIO Pressures Plot -~ T6g -~ IA -~-- OA OOA -~- OOOA On ~ • 11 /1A109 11/21/09 11!28109 12/05/09 12112!09 12/19109 12!26109 01!02110 01!09!10 U1 /1kSllU u~rl~n u u vsu~iu uuuc~iu uu i311D TREE = FMG WELLHEAD = ClW ACTUATOR = AXELSON KB. ELEV = 64.6' BF. ELEV = KOP = W -_ Max Angle = 5540' r...w...., ..,,, 100 @ 11038' ___ __ Datum MD = N/A Datum TV D = 8800' SS 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 13-318" CSG, 68#, L-80, ID = 12.415" 2926' 3540' TOP OF 7" LNR ~--i 8651' F 9-5/8" CSG, 47#, NT-80S, ID = 8.681" 8962' 3-1/2" TBG, 9.2#, L-80, TDS, .0087 bpf, ID = 2.990" 905( Minimum ID =1.920" @ 9344' 2-3i$" LINER EST TOP OF CEMENT 9338' TOP OF 2-318" LNR 9344_ TBG PUNCH (06(06(02} 9502'-95( WFD WHIPSTOCK (07!06(05) 9663' RA TAG 9668' 3-112" BKR CIBP (SET 619/05} 9765' CT PERFORATION SUMMARY REF LOG: ??? ANGLE AT TOP PERF: 87 @ 10340' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/5qz DATE 1-9/16" 6 10340 - 10450 O 07/16105 1-9116" 6 10490 - 10580 O 07!16/05 1-9/16" 6 10650 - 10840 O 07116/05 1-9/16" 6 11230 - 11280 O 07/16/05 1-9/16" 6 11320-11460 O 07116/05 1-9/16" 6 11720 - 11770 O 07!16/05 1-9/16" 6 11890 - 12170 O 07/16/05 7" LNR, 27#, NT-80, NSCC .0383 bpf, ID = 6.276" (-j 110$4, 4-1/2" 5LTD LNR, 12.63#, L-80, 11728' FL4S, .0152 bpf, ID - 3.958" 1 ~ -~ ~ ~ SA TES: TRDP PARTIALLY LOCKED OUT; CONTR LINE NOT HOLDING PSI (09/18!08) 207$` 4-1/2" CAMCO TRDP-4A, SSSV NIP, ID = 3.812" 2078' HOLD OPEN SLV ON 4-1/2" DB LOCK w 13.84" NO GO, ID = 2.24" (09/22108} 2J2$' --~4-1/2" X 3-112" XO, ID = 2.990" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3189 3188 2 MMG-2 DMY RK 16 07!23/05 2 5498 5494 9 MMG-2 DMY RK 20 07/23(05 3 6971 6872 29 MMG-2 DMY RK 0 08/29/03 4 8378 7984 50 MMG-2 DMY RK 0 08/29/03 5 8503 8062 53 MMG-2 DMY RK 0 08129!03 9031' - ' 3-112" PKR SWS NIP, ID = 2.813" 9050' 3-112" X 4-112" X0, ID = 3.00" 9053' 7" X 4-1i2" BKR S-3 PKR, ID = 3.930" 9057' 4-1/2" X 3-1/2" XO, ID = 3.00" 9071' 3-112" PKR SWS NIP, ID = 2.813" 9338' 3" PB BKR DEPLOY SLV, ID = 2.250 9344' (-~ 2-314" X 2-3/8" XO, ID = 1.920" MILLOUT WINDOW (15-318) 9663' - 9668' I DATE REV BY COMMENTS DATE REV BY COMMENTS 10!01(92 ORIGINAL COMPLETION 10/02/08 KJB/TLH HOLD OPEN SLV SET & SFTY NOTE 09/01!93 LAST WORKOVER 06/16/02 JDMIKK CTD SDTRCK {15-31A) 07/17/05 NORDIC 1 CTD SDTRCK (15-31 Bi 07/23/05 JAR/PJC GLV CIO 03/05/07 MWS/PJC DRLG DRAFT CORRECTIONS 12174' I-i PBTD I I 2-318" LNR, 4.7#, L-80, STL, ( 12210` .0039 bpf, ID = 1.920" PRUDHOE BAY UNIT WELL: 15-31 B PERMIT No: 2050860 API No; 50-029-22285-02 SEC 22, T11 N, R14E, 4597.85' FEL & 2653.89' BP Exploration (Alaska} BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 by Mr. Tom Maunder uC ,., ~~~ Alaska Oil and Gas Conservation Commission ~,~ y ~ I 333 West 7th Avenue ~~ Jr Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 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, Anna Dube. 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) DS-15 natP~ nvns~~n Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-01 B 2042570 50029206960200- NA Sealed NA 15-028 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-046 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11 /10/2009 15-OSC 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11 B 2041460 50029206530200 NA Sealed NA 15-126 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7!2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-258 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-266 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-29B 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-318 2050860 50029222850200 NA 1.2 NA 3.4 11/1112009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-338 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-366 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-378 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-41B 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-42B 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-458 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-486 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-49B 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 l 7 r~,.~ DATA SUBMITTAL COMPLIANCE REPORT 7/1912007 Permit to Drill 2050860 Well Name/No. PRUDHOE BAY UNIT 15-31B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22285-02-00 MD 12210 TVD 8802 Completion Date 7/17/2005 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes/~ DATA INFORMATION Types Electric or Other Logs Run: MWD / NGP GR / ROP, Memory CNL Well Log Information: Log/ Electr Data Digital Dataset T~e Med/Frmt Number Name ~D D Asc Directional Survey C Lis 13322 Neutron /Cog Neutron /ED Q Lis i.34'Ti L49•'der111C~tlvfl ~7 "~ ~ ~ ~ t ~3 '!t /~tpt ~l. ' ~~ - ~24 ~ 1 LIS Verification QED C Pdf 13896 Rate of Penetration QED C Pdf 13896 Gamma Ray QED C Lis 13896 Induction/Resistivity (data taken from Logs Portion of Master Weli Data Maint Log Log Run Scale Media No Interval Start Stop OH / CH Received Comments 432 12210 Open 9/7/2005 IIFR 1 8686 12175 Case 10/19/2005 LDWG Edit of Memory CNL Blu 1 8686 12175 Case 10/19/2005 Memory Compensated Neutron Log Memory GR/CCL/CNL 16 July 2005 290 9 187 6~ttr- 12/7/2005 GR/ROP a _ Q 7• ~ 1 ' 2. $ 7 e6 r~ i ~'F i 12/7/2005 L4~-S6Pifi-EF~ft+TY G 5,7,9 9667 12210 5/10/2006 ROP DGR 5-Jul-2005 5,7,9 8565 8736 5/10/2006 DGR 5-Jul-2005 9290 12211 Open 5/10/2006 GR, ROP Well Cores/Samples Information: Interval Name Start Stop ADDITIONAL INFORMATION Well Cored? Y Chips Received? '1~1-ld" Analysis ~T1Q~ Received? Sample Set Sent Received Number Comments Daily History Received? Formation Tops Gomments: DATA SUBMITTAL COMPLIANCE REPORT 7/19/2007 Permit to Drill 2050860 Well Name/No. PRUDHOE BAY UNIT 15-31 B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22285-02-00 MD 12210 TVD 8802 Completion Date 7/17/2005 Completion Status 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: Date: aas -o~s~ i 3~59~ WELL LOG TRANSMITTAL To: State of Alaska Apri127, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 15-31 B, 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 15-31B: LAS Data & Digital Log Images: 50-029-22285-02 1 CD Rom 5(r5'~o~ C'~ • ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska (ail and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7°i Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 15-31 B, November 22, 2005 %~4I`~ X05 ~~(o AK-MW-3802816 1 LDWG formatted Disc with verification listing. API#: 50-029-22285-02 PLEASE ACKNOWLEDGE RECEII'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petro-Technical Data Center LR2-1 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 9908 Date: a' D Signed: RECEIVE'p DEC 0 7 ~Q05 ~ U(1 & Gas Cons. Cannal~ 10/18/05 ~chlumberger Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wou i„ti e NO. 3503 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ~ ,.,. n.,e.. ...:,... NK-20 10889223 PPROF W/DEFT 03/21105 1 P2-34 11072853 TEMPERATURE PRESSURE LOG 06105/05 1 N-14A 10991753 LDL 01122/05 1 4-381K-34 10933591 PPROF WIDEFT/GHOST 10129104 1 8-19A 11058502 RST 05106105 1 1 15-31B 10942223 MCNL 07/16/05 1 ~ 1 ' MPF-89 11132060 SCMT (PDC-GR) 10/08/05 1 1 DS 16-01 10980601 INJECTION PROFILE 08/15/05 1 DS 16-15 10980599 PPROF W/DEFT 08/13/05 1 DS 09-10 11058237 INJECTION PROFILE 08116/05 1 M-30 11072877 INJECTION PROFILE 08/04/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 D ~ Date Delivered: I ~ , T Alaska Data & Consulting Services 2525 Gambell Street, S to 400 Anchorage, AK 99503- 838 ATTN: Beth O Received by: • • ao~ - o~~ F~I.~ • 11-Aug-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 15-31 B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 432.24' MD Window /Kickoff Survey: 905.03' MD (if applicable) Projected Survey: 12,210.00' 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 Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 rl ~ f ((/{~f Date ~~ "`~~ ` Signed r ~``'~`"'~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COM iSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG .. ~.'a` ~ ..~ a AEG Zv05 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 ry r1>" ~~Efipl ISSE ^ GINJ ^ WINJ ^ WDSPL No. of Com ietions One P Other ^ StratigraphlG;,; ice 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 7/17/2005 205-086 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 7/8/2005 50-029-22285-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 1937' SNL 1438' EWL S C 7/14/2005 15-31 B , , E . 22, T11N, R14E, UM Top of Productive Horizon: g. KB Elevation (ft): 15. Field /Pool(s): 2552' SNL 4379' EWL SEC 22 T11N R14E UM 64.6' Prudhoe Bay Field / Prudhoe Bay , , . , , , Pool Total Depth: 9. Plug Back Depth (MD+TVD) 3800' SNL, 651' EWL, SEC. 23, T11N, R14E, UM 12174 + 8806 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surtace: x- 6 77389 y- 595 9578 Zone- ASP 4 12210 + 8802 Ft ADL 028307 _ _ __ _ __ __ _ TPI: x- 680344 y-_5959033 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 6gi928 y- 5957823 Zone- ASP4 (Nipple) 2078' MD ----~----~--~--- --~-- --~--------- ---~----'---- 19. Water depth, if offshore 20. Thickness of Permafrost i8. Directional Survey ®Yes ^ No N/A MSL 1900' (Approx.) 21. Logs Run: MWD / NGP GR / ROP, Memory CNL 2• CASING, LINER AND EMENTING RECORD CASING ETTING EPTH MD ETTINC~ EPTH TVD HOLE AMOUNT... $IZE Wr. PER FT, GRADE OP TTOM OP TTOM SIZE CEMENTING RECORp PULLED 20" 94.5# H-40 Surface 110' Surface 110' 30" 000# Coldset II 13-3/8" 68# L-80 36' 3524' 36' 3524' 16" 2554 cu ft CS III, 460 cu ft Class 'G' 9-5/8" 47# NTSOS 32' 8952' 32' 8324' 12-1/4" 1644 cu ft Class'G' 506 cu ft Class 7" 26# NT80S 8651' 9662' 8148' 8628' 8-1/2" 93 cu ft Class'G' 2-3/8" 4.7# L-80 9338' i 2210' 8510' 8802' 3" 84 cu ft Class 'G' 23. Perforations open to Produc B l I t Si N tion (MD + TV D of Top and " " 24. TuBIriG RECORD ottom n erva , ze and umber; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 1.56" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 x 9662' 9053' MD TVD MD TVD 3-1/2", 9.2#, L-80 10340' - 10450' 8838' - 8840' 10490' - 10580' 8839' - 8842' 25. ACID, FRACTURE, CEMENT 'SQUEEZE, ETC. 10650' - 10840' 8843' - 8841' 11230' - 11280' 8824' - 8826' DEPTN INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 11320' - 11460' 8827' - 8835' ' ' 2500' Freeze Protect w/ McOH 11720 - 11770' 8821 - 8816' 11890' - 12170' 8808' - 8806' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.j: July 25, 2005 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 8/17/2005 4.2 TEST PERIOD 311 2,280 -0- 83.86 7,322 Flow Tubing Casing Pressure CALCULATED E OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) Press. 82 1,050 24-HOUR RAT 1,780 13,031 -0- 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". C01l4PLE'; tON ~ ~ -~ w~ IV~~` uJ ~~b/ ~~ ~ ~~Z ~ ~U+~ N ~ ~ one J ~ ~ ;,.r. cg. ~" 7(lpri ~ ~ IED ~~ ~ ~ I r• • ~ ~ I • ~ ~ . _.~_ : G C.. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE v~ 2f3. , GEOLOGIC MARKERS 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". 23SB /Zone 26 9668' 8630' None 22TS 9800' 8684' 21TS /Zone 2A 9933' 8732' Zone 1 B 10073' 8775' Zone 1 A / TDF 10170' 8800' 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 O~ ''~' Q 15-31 B 205-086 Prepared ey Name/Number.• Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Driving engineer: Mary Endacott, 564-4388 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). been S: 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). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only C~ BP EXPLORATION Page 1 of 13 Operations Summary Report Legal Well Name: 15-31 Common Well Name: 15-31 Spud Date: 9/6/1992 Event Name: REENTER+COMPLETE Start: 6/28/2005 End: 7/17/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date I; From - To 'I Hours ~ Task ~ Code NPT Phase 7/4/2005 09;00 - 10:30 1.50 MOB P PRE 10:30 - 11:00 0.50 MOB P PRE 11:00 - 11:30 0.50 MOB P PRE 11:30 - 12:00 0.50 MOB N SFAL PRE 12:00 - 16:30 4.50 MOB P PRE 16:30 - 18:30 2.00 WHSUR N WAIT PRE 18:30 - 18:45 0.25 WHSUR N SFAL PRE 18:45 - 19:00 0.25 WHSUR N DPRB PRE 19:00 - 22:30 3.50 WHSUR N DPRB PRE 22:30 - 00:00 I 1.501 WHSUR I N 00:00 - 00:30 I 0.501 WHSUR I N DPRB IPRE SFAL IPRE 00:30 - 02:00 1.50 WHSUR N WAIT PRE 02:00 - 02:30 0.50 WHSUR N DPRB PRE 02:30 - 02:45 0.25 MOB P PRE 02:45 - 03:00 ~ 0.25 ~ MOB ~ P ~ ~ PRE 03:00 - 05:00 2.00 RIGU P PRE 05:00 - 11:00 6.00 BOPSU P PRE 11:00 - 11:30 0.50 BOPSU P PRE 11:30 - 12:00 0.50 BOPSU N WAIT PRE 12:00 - 13:15 1.25 KILL P PRE 13:15 - 14:00 0.75 KILL N DPRB PRE 14:00 - 14:15 I 0.251 KILL I N I DPRB IPRE Description of Operations Rig released from 18-12B @ 09:OOHrs on 7/4/2005. Prep to move rig off well. Jack-up rig & pull rig off well. Secure location. Clean location & fold herculite. Held pre-move safety meeting with crew, security & tool services. Move rig from DS#18. Repair leaking clutch flush hose on drive motor #2. Move rig to DS#15. Position rig in front of 15-31. Install dikes around tree & lay herculite in front of well. Confirm WHP of 1700psi on 15-31. Also observe slight leak from blind on wing valve. Cannot load & kill well due to low infectivity rate (0.75bpm/3000psi) thru tbg punches. W.O. Grease Crew. Grease Crew repair leaking blind on wing valve & grease tree valves. Held PJSM for venting/bleeding off WHP. Inform DSO & BP Control Room of gas venting. Secure WHD & hook up gas venting hose. Bleed down WHP by venting to 240psi. Pressure test master & swab valves with WHD pressure. Master is holding but swab is leaking. Call for grease crew. Meanwhile continue venting gas. Pressure buildup rate = 4psi/min. Suspect gas in coming from 9656' - 81' perfs above the CIBP. Review situation with ANC & decide to shut-in SSSV. DSO shut-in SSSV -not holding. Grease crew grease & reservice all tree valves. Tested all valves OK. Nordic ANC Management not comfortable with moving rig over well with only surface barriers, thus call for BPV. SI master & swab valves. Final WHP = 200psi. W.O. Valve Crew. Valve crew install BPV on 15-31. Final WHP = 350psi. PJSM. Review procedure, hazards & mitigation for backing rig over well. Back rig over well & set down. Accept rig @ 03:OOHrs on 7/5/2005. N/U BOPE. Meanwhile spot outside trailers & tanks. Perform initial BOPE function/pressure test. AOGCC test witness waived by Chuck Schevy. PT inner reel valve to 3500 psi. Meanwhile R/U hardline to tiger tank & P/test to 4000psi. Fill rig pits with 1% KCL-water. Change packoff. Cut coil and need to weld on coil connector. Pump across top to clean out coil of any residual methanol left from FP on DS18-12B. Only LEL on rig possibly not working. DSO came out & sniffed rig floor. GBR weld-on new CTC. PT CTC to 3800 psi & pull test to 40k. PJSM. Valve crew retrieve BPV. Pump open SSSV & install fuseable cap. Observe WHP of 1750psi. Held pre-operations safety meeting. Reviewed well kill plan, gas venting procedures & hazards. Inform DSO & BP Control Room of gas venting. Position motorman with loader @ a safe distance to warn incoming vehicles to stay clear of the tiger tank area. Printed: 7!18/2005 11:22:52 AM BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: 15-31 Common Well Name: 15-31 Spud Date: 9/6/1992 Event Name: REENTER+COMPLETE Start: 6/28/2005 End: 7/17/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT ~ Phase Description of Operations 7/5/2005 14:15 - 14:45 0.50 KILL N DPRB PRE M/U nozzle BHA#1 to injector. Stab on well & strip in nozzle. Open up master valve. 14:45 - 16:50 2.08 KILL N DPRB PRE Snub in hole while venting gas to tiger tank. Continue RIH & lightly tag CIBP ~ 9760'. PUH to 9750'. 16:50 - 19:00 2.17 KILL N DPRB PRE Circ out gas C~ 2.19bpm/3200psi. Stop at 2 bottoms up. 19:00 - 20:00 1.00 KILL N DPRB PRE Shut down pumps. Observe well. No flow. 20:00 - 00:00 4.00 KILL N DPRB PRE CBU. 7/6/2005 00:00 - 00:30 0.50 KILL N DPRB PRE 00:30 - 01:30 1.00 KILL N DPRB PRE 01:30 - 02:30 1.00 KILL N DPRB PRE 02:30 - 03:30 1.00 KILL N DPRB PRE 03:30 - 05:00 1.50 KILL N DPRB PRE 05:00 - 06:30 1.50 WHIP P WEXIT 06:30 - 06:45 0.25 WHIP P WEXIT 06:45 - 07:30 0.75 WHIP P WEXIT 07:30-08:001 0.501WHIP IP I IWEXIT 08:00 - 09:45 f 1.75 i WHIP I P I IWEXIT 09:45 - 10:20 0.58 WHIP P WEXIT 10:20 - 10:40 0.33 WHIP P WEXIT 10:40-10:55 0.25 WHIP P WEXIT 10:55 - 12:20 1.42 WHIP P WEXIT 12:20 - 14:00 1.67 WHIP N DFAL WEXIT - Hole took 4 bbls to fill. - Gas to surface at 35 bbls pumped, 1/2 bottoms up -- gas migration. - Additional gas to surface at bottoms up. - 2.1 bpm at 2000 psi. - SIWHP at 150 psi. Order 9.0 ppg weighted brine. Continue circulating. Circulate well to 9.0 ppg kill weight fluid. - Double slick KCI. - 2.1 bpm at 1380 psi. Monitor well CBU. - Returns in less than 1 bbl. - No gas returns at 1.5 BU. POOH at 2.1 bpm. PU WS setting assembly. - install two RA pip tags in Whipstock. RA PIP tag to TOWS = 5.7'. PJSM for M/U &RIH WFD LSX WS. M/U WFD LSX whipstock, setting sleeve, Fury setting tool, BKR FAIV, Sperry GR/MWD, orienter & MHA (OAL = 70.35']. Scribe tools, mark orienter & M/U injector. GR to BOWS = 35.34'. RIH with WFD LSX whipstock BHA #2 to 100'. SHT MWD with 0.8bpm/1100psi - OK. Orient 2 clicks. PUH to surface. P/U injector & check orienter -got 2 for 2 clicks. Continue RIH BHA#2. Wt check ~ 9500' - Up = 28k, Down = 19k. RIH & lightly tag CIBP @ 9758'. P/U to up wt & correct CTD to 9765' (ELMD). PUH to 9760 for MWD tie-in. Log up from 9760' to 9734' C~3 0.8bpm/1100psi & tie-into Geology PDC log. Subtract 1.5' from CTD. Check TF - Q 70L. PUH to 9660' while orienting TF to 167ROHS. RBIH to 9669.2' with TOWS @ 9660'. 3-1/2" Tbg collar @ 9656' & 7" Lnr collar ~ 9657' (from pipe tally). Circ @ 2.Obpml3900 psi for 2mins. Drop pump to Obpm. Wait 3mins. Bring on pump to 0.6bpm, pressure up & shear off WS 2100psi. Continue pumping & observe TF of 172ROHS. Set down 2k @ 9670' - WS held. POOH with WS setting BHA#2 filling the hole via the backside with 100psi WHP. Paint EOP flag ~ 8900'. Continue POOH & O/pull 3x C~3 2093' (SSSV). Check fuseable cap on SSSV -- seems OK. Call out DSO to pump open SSSV. Meanwhile orient 2 clicks & attempt to pull up past SSSV - no luck. Pump control line from 2000psi to 4400psi & try to pull thru ~ SSSV pressure kept dropping back to 2000psi. Install SSSV accumulator panel & pump open Printed: 7/18/2005 11:22:52 AM BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/6/2005 7/7/2005 15-31 15-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To ~ Hours Task 1 Code NPT _ __ ~ 12:20-14:00 ~ 1.67 WHIP ~N DFAL 14:00-14:15 I 0.251WHIP IP 14:15-15:00 I 0.751WHIP IP 15:00 - 15:15 0.251 ZONISO P 15:15 - 15:30 0.25 ZONISO P 15:30 - 16:00 0.50 ZONISO P 16:00 - 17:20 I 1.331 ZONISO I P 17:20 - 17:30 0.17 ZONISO P 17:30 - 18:00 0.50 ZONISO P 18:00 - 18:20 0.33 ZONISO P 18:20 - 18:30 0.17 ZONISO P 18:30 - 19:45 ~ 1.25 ~ ZONISO ~ P 19:45-20:45 ~ 1.OO~STWHIP~N AWAIT 20:45 - 21:30 0.75 STWHIP P 21:30 - 23:20 1.83 STWHIP P 23:20 - 00:00 I 0.671 STWHIPI P 00:00 - 00:30 0.50 STWHIP P 00:30 - 02:00 1.50 STWHIP P 02:00 -04:00 2.00 STWHIP P 04:00 - 05:30 1.50 STWHIP P 05:30 - 06:30 1.00 STWHIP P 06:30 - 08:30 I 2.001 STWHIPI P 08:30 - 09:15 I 0.751 STWHIPI P Spud Date: 9/6/1992 Start: 6/28/2005 End: 7/17/2005 Rig Release: Rig Number: N1 Phase '; Description of Operations WEXIT SSSV with 4800psi. Total of 2.5gals of hydraulic fluid pumped. Pull BHA thru SSSV. WEXIT Continue POOH with WS setting BHA#2. SSSV panel reading 4400psi. WEXIT UD WS setting BHA#2. Observe indentation on WFD Fury setting tool indicating where BHA was hanging up on the SSSV flapper. WEXIT M/U slick cementing nozzle BHA#3. SSSV panel reading 4100psi. Call out grease crew to pump up SSSV again to +/-5000psi. WEXIT RIH with cementing nozzle to 1950'. WEXIT Confirm infectivity rate ~ 1.04bpm/1950psi. Meanwhile grease crew pump up SSV panel back up to 5000psi. WEXIT RIH with nozzle to 2200' (below SSSV). PUH clean to 2000' (above SSSV). Continue RIH & tag WS 2x @ 9657'. Correct CTD to 9660'. PUH 10' to 9650' & flag CT. Meanwhile RU SLB Cementers & prime up. WEXIT PJSM with all personnel concerning cementing operations. WEXIT Flush/PT lines to 4k. Mix & pump 8 bbls 15.8 ppg class 'G' cmt slurry & 5bbls of water behind C~3 2.0/2.Obpm & 2650 psi. Chase with KCL water @ 2.38/2.29 bpm & 2750 psi. Pump out 1 bbl of cmt past nozzle. Shut-in choke. Pump 5 bbls away at 2000 psi, no squeeze pressure obtained. Open up choke. Lay-in remaining cmt 1:1. WEXIT POOH to safety C~ 8000'. WEXIT Shut-in well with 1000psi WHP & W.O.C. to swap out. Squeeze in additional 2bbls of cmt. Leave ibbl of cmt above WS. WEXIT POOH circ ~ 0.4bpm/333psi to replace voidage only.UD Cementing BHA. WEXIT Discuss utilizing bent motor to C/O cement w/ David Hearn. David felt that there was too much potential for tubing damage. Suggested that we utilize a straight motor to C/O Cement and mill first foot of window. Discussed w/ODE and agreed. Ordered straight motor from BOT. Wait on same. WEXIT M/U 2.73" Mill with BOT X-Treme Motor BHA. WEXIT RIH w/ window milling BHA. -Circulate minumum rate. WEXIT Tag @ 9,658'. Wash out cement. Circulate 1/2 Bio. - Circulate minumum rate attempting to find top of cement. - Tag TOWS. -Circulate at max rate to clear well bore of green cement. - No tie in due to lack of significant formation marker. WEXIT Continue circulating cement out & 1/2 Bio. in. WEXIT WOC for UCA of 500 psi compessive strength. WEXIT Mill from 9,660' to 9,661'. All parameters in line. WEXIT POH, UD staight Milling BHA #4. WEXIT P/U & M/U Bent housing, window milling BHA. - WF motor dressed with new output shaft. WEXIT RIH. -Surface test orienter. - Tie in to flag, +4'. WEXIT Orient TF to 120L. - Dry tag whipstock at 9661' MD. Printed: 7/18/2005 11:22:52 AM l__J BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: i 15-31 15-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/28/2005 Rig Release: Rig Number: N1 Date :From - To Hours ! Task 'Code , NPT I, Phase 7/7/2005 08:30 - 09:15 0.75 STWHIP P WEXIT 09:15 - 11:15 2.00 STWHIP P WEXIT 11:15-12:30 1.25 STWHIP N DFAL WEXIT 12:30- 14:00 1.50 STWHIP N DFAL WEXIT 14:00-16:00 2.00 STWHIP N DFAL WEXIT 16:00 - 00:00 I 8.001 STWHIP( P I I WEXIT 7/8/2005 100:00-02:15 I 2.251STWHIPIP I (WEXIT 02:15 - 04:00 ~ 1.75 ~ STWHIP P ~ ~ WEXIT 04:00 - 05:30 1.50 STWHIP P WEXIT 05:30 - 06:20 0.83 STWHIP P WEXIT 06:20-08:20 I 2.OOISTWHIPIP I (WEXIT 08:20 - 09:20 ~ 1.00 ~ STWHIP P ~ ~ WEXIT 09:20 - 10:20 1.00 STWHIP P WEXIT 10:20 - 12:20 2.00 STWHIP P WEXIT Page 4 of 13 Spud Date: 9/6/1992 End: 7/17/2005 Description of Operations - PU 28k, SO 16k. RIH, stall at 9658' MD. Mill dual string (3-1/2" x 7") low side window. - TF at 160E - 1.5 bpm - Free spin at 2240 psi. - 200 - 300 psi (potentially motor work) - 1-3k WOB, drilling off - Time milled from 9658.0 - 9660.7' MD. -Sperry pulser failure. - Prior to POOH, RIH with 5k WOB and no identifiable motor work. POOH for sperry pulser. Stand back injector. Change out pulser, orienter, motor, and mill. - Mill showed center damage, .indicating that we were further down the whipstock face than earlier thought. Will adjust depth when back on bottom with BHA #5. - W F motor dressed with new output motor. RIH with window milling BHA #6, circulating minimum rate. - Surface test orienter - Tie into flag at 9558.1' MD, correct 3.5' to 9661.6' MD. - PU 27.5k, SO 16.5k - Free spin at 3,100 psi at 1.5 bpm. Mill window from 9661.2' MD. - TF at 157L. - Correct depth to 9663.2' - Time mill from 9663.2' to 9667', 1.5 BPM to 1.7 BPM ~ 3200 psi. to 3800 psi. Time Mill Window from 9667' to 9668'. Pressure spike to 4000 psi @ 9667.7' followed by loss of 2000 Ibs of bit wt. indicates mill is out of window into formation. Milled formation from 9668' to 9669' -stacked up to 12K WOB - would mill no further. Circulated bottoms up -sample showed quartz sand, some chert & cement. Pumped 2 Ib/bbl Bio sweep to bit. POH w/ BHA #5 chasing up sweep. L/D H/C fat radius mill and 2.5 bent housing motor. P/U 1.75 adj. bent housing motor & 2.74 diamond WFD Crayola mill. -WFD motor dressed with new output shaft. RIH with BHA - Correct to flag at 9659.1' MD, correct +4.2' to 9663.8' MD - Orient 135 LOHS - RIH pumping minumum rate, stack at 9668' MD. - PU 27.5k, SO 17.5k Ream window at 1.5 bpm, 3000 psi free spin. -Stall at 9660' MD. Ream down at 0.4 fpm. - Exited window at 9667.7' MD. - Mill ahead to 9669.5' MD. Orient to 135 ROHS Ream window at 1.5 bpm, 3000 psi free spin. - Ream down at 0.4 fpm. - Stall at 9666.4' MD. Printed: 7/18/2005 11:22:52 AM BP EXPLORATfON Page 5 of 13 Operations Summary Report Legal Well Name: 15-31 Common Well Name: 15-31 Spud Date: 9/6/1992 Event Name: REENTER+COMPLETE Start: 6/28/2005 End: 7/17/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 I :, Date 1 From - To ~, Hours Task Code ~ NPT Phase ~ Description of Operations 7/8/2005 10:20 - 12:20 2.00 STWHIP`.. _ __! _ __ __ _ __ __ _- _ ___ P WEXIT -Stack weight at 9669.2' MD. 12:20-12:45 0.42 STWHIP P WEXIT 12:45 - 13:30 0.75 STWHIP P WEXIT 13:30-14:00 I 0.501STWHIPIP I IWEXIT 14:00 - 16:00 2.00 STWHIP P WEXIT 16:00 - 16:30 0.50 STWHIP P WEXIT 16:30 - 17:00 0.50 DRILL P PROD1 17:00 - 18:45 1.75 DRILL P PROD1 1.8:45 - 20:30 1.75 DRILL P PROD1 20:30 - 21:00 0.50 DRILL P PROD1 21:00 - 22:30 1.50 DRILL P PROD1 22:30 - 23:00 0.50 DRILL P PROD1 23:00 - 00:00 1.00 DRILL P PROD1 7/9/2005 00:00 - 01:00 1.00 DRILL P PRODi 01:00 - 02:30 1.50 DRILL P PRODi 02:30 - 05:30 3.00 DRILL P PRODi 05:30 - 05:45 0.25 DRILL N DFAL PROD1 05:45 - 06:15 0.50 DRILL P PROD1 06:15 - 06:45 0.50 DRILL P PROD1 06:45 - 10:15 3.50 DRILL P PROD1 10:15 - 10:30 I 0.251 DRILL I P I I PRODi Orient TF to 180 ROHS Ream window at 1.5 bpm, 3000 psi free spin. - Pump 20 bbls bio sweep. - Follow with flo pro light. Dry tag. Ok. Tag TD at 9669.7' MD, approximately 2' outside window. - Attempt to make hole with mill. No go. POOH with window dressing mill. - Paint EOP flag at 9500' MD. Lay out motor and mill. PU 1,3 deg baker motor and HCC 3" BC. - Surface test orienter. RIH. EOP flag C~ 9500' 90+ ft high. Tie in with GR -spike ~ 9,411'. - Checked counter wheel, chains, etc. No problems. - Verified flag painted in the correctposition. - Potentially tied into wrong flag. EOP flag C~3 9500' 90+ ft high. Tie in with GR -spike @ 9,411'. Subtract 86' for depth correction. Orient to i40 deg. R. Slip through window to 9668'. Start drilling -stalling out C~3 9669.5' to 9669.6'. Continue drilling to 9680'. 1.5 BPM w/ 2800 psi off bottom, 3100 psi on bottom. WOCT = 3000 Ibs to 3500 lbs. P/U Wt. = 24K DN Wt. = 16K Orient to 90 deg. right. Continue drilling from 9680' to 9705'. 1.5 BPM C~? 3150 psi. on & 2800 psi. off. TF 90 deg right. WOCT 3500K to 4000K. P/U - 25K S/O = 17K. - NOTE: RA tag on whipstock P/U by GR @ 9,668' - Top of Window @ 9,662.3' - Bottom of Window (slide) C~ 9,667.2' Directional Drill from 9,705' to 9,732'. Orient TF i35 R to 90 R. Difficult in gaining and maintaining orientation. Directional drill from 9,732' to 9,803' - 1.55 to 1.6 BPM @ 3090 psi. to 3145 psi. - ROP = 22 to 37 ft/hr Puller failure. POH. Puller began working again. Drill ahead from 9803' - 9825'. - 140R TF - 50 - 70 fph ROP - 1.56 / 1.56 bpm - 2850 psi free spin. - Drilling at 3000 psi, 14k CT wt. Orient to 90 L. Drill ahead from 9825' - 9900'. - 50 - 70 fph ROP - 1.56 / 1.56 bpm - 2850 psi free spin. - Drilling at 3000 psi, 14k CT wt. Wiper trip to window. Printed: 7/18/2005 11:22:52 AM BP EXPLORATION Page 6 of 13 Operations Summary Report Legal Well Name: 15-31 Common Well Name: 15-31 Spud Date: 9/6/1992 Event Name: REENTER+COMPLETE Start: 6/28/2005 End: 7/17/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Hours Task I Code ~ NPT j Phase - -Date From - To -~ __ _- 7/9/2005 10:30 - 11:15 0.75 DRILL P PRODi 11:15 - 11:30 0.25 DRILL P PRODi 11:30 - 15:30 4.00 DRILL P PROD1 15:30 - 15:45 0.25 DRILL P PROD1 15:45 - 19:00 3.25 DRILL P PROD1 19:00 - 19:30 0.50 DRILL P PROD1 19:30 - 21:00 1.50 DRILL P PROD1 21:00 - 00:00 3.00 DRILL P PROD1 7/10/2005 100:00 - 02:15 I 2.251 DRILL I P I I PROD1 02:15 - 03:00 0.75 DRILL P PROD1 03:00 -04:50 1.83 DRILL P PRODi 04:50 - 06:45 1.92 DRILL P PROD1 06:45 - 08:15 1.50 DRILL P PRODi 08:15 - 10:30 2.25 DRILL P PROD1 10:30 - 11:30 1.00 DRILL N DFAL PROD1 11:30 - 12:15 0.75 DRILL N DFAL PROD1 12:15 - 13:45 1.50 DRILL N DFAL PROD1 13:45 - 14:15 0.50 DRILL P PROD1 14:15 - 14:30 0.25 DRILL P PROD1 14:30 - 15:00 0.50 DRILL P PROD1 15:00 - 16:00 1.00 DRILL P PROD1 Description of Operations Inspect SCRs while waiting in cased hole. RIH to 9900' MD. Drill ahead from 9900' - 10027' MD. - 50 - 70 fph ROP -1.62/1.65bpm - 3000 psi free spin. - Drilling at 3400-3500 psi, 12k CT wt. Wiper trip to the window. Drill ahead from 10027' to 10,164' MD. - TF high side, orient as required to maintain tool face. - 50 - 70 fph ROP -1.62/1.65bpm - 3350 psi free spin. - Drilling at 3600-3700 psi, 10k CT wt Wiper trip to the window. Orient for TF 90 deg. right of high side, orient as required to maintain tool face. Drill ahead from 10,164' to 10,271' MD. - TF 95 -100 deg. right of high side, orient as required to maintain tool face. - 24 - 60 fph ROP - 1.58 / 1.61 bpm - 3350 psi free spin. - Drilling at 3680-3750 psi, 10k CT wt Drill from 10,271' to 10,305 '. -Hole getting sticky -difficult to orient & maintain WOB. Change out to new FLO-PRO Mud on-the-fly. - Free spin w/ new mud - 2800 psi. - i.5B to i.63 BPM C~ 3180 psi to 3220 psi. -Orient straight Up -will land 10 to 12 ft. early per Geo. - Up Wt. = 25,600, Dn Wt. = 16,000 Wiper trip to shoe Drill from 10,305 ' to 10,377'. Landed to Horizontal. -Free spin w/ new mud - 2800 psi. - 1.58 to 1.63 BPM @ 3030 psi to 3080 psi. - Orient straight Up -will land 10 to 12 ft. early per Geo. - Up Wt. = 25,600, Dn Wt. = 16,500 POH to adjust motor bend, change out pulsar & LWD probe. Change out orienter and pulser. Decrease bend to 1.1 deg. Replace bit with rebuilt HCC 3" BC. -Surface test orienter. - Bit graded 5-5-BT-A-X-I-WT-BHA RIH with BHA #9. - Attempt to orient through window. - Pulser not working. POOH for pulser. Change out pulser and probe. RIH with BHA #10. Run in through window. Tie in to RA and GR. Correct +2 feet. RIH to 10,379' MD. MAD pass at 3'/min. Drill to 10466' MD. - Free spin - 2800 psi. Printed: 7/18/2005 11:22:52 AM BP EXPLORATION Page 7 of 13 Operations Summary Report Legal Well Name: 15-31 Common Well Name: 15-31 Spud Date: 9/6/1992 Event Name: REENTER+COMPLETE Start: 6/28/2005 End: 7/17/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 - Orient TF 85L - Up Wt. = 27,500, Dn Wt. = 16,500 - ROP at 140-180 fph. 16:00 - 16:30 0.50 DRILL P PROD1 Orient to 100 LOHS. 16:30 - 17:45 1.25 DRILL P PROD1 Drill to 10,550' MD. - Free spin - 2600 psi. - 1.45 to 1.50 BPM ~ 3000 to 3300 psi. - Up Wt. = 27,500, Dn Wt. = 16,500 - ROP at 140-180 fph. 17:45 - 18:00 0.25 DRILL P PROD1 Wiper trip to window. 18:00 - 21:00 3.00 DRILL P PROD1 Drill to 10,700' MD. - Free spin - 2700 psi. - 1.52 to 1.62 BPM ~ 3000 to 3300 psi. - Up Wt. = 27,500, Dn Wt. = 16,500 - ROP at 24 - 140 fph. 21:00 - 22:00 1.00 DRILL P PROD1 Wiper trip to window. 22:00 - 23:30 1.50 DRILL P PROD1 Drill to 10,845' MD. - Free spin - 2800 psi. C~ 1.55 BPM - 1.52 to 1.62 BPM @ 3250 to 3300 psi. - Up Wt. = 25,500, Dn Wt. = 16,000 - ROP at 80 - 140 fph. 23:30 - 00:00 0.50 DRILL P PROD1 Wiper trip to window. 7/11/2005 00:00 - 01:00 1.00 DRILL P PROD1 Wiper Trip to Window 01:00 - 04:00 3.00 DRILL P PROD1 Drilf to 10,950' MD. - Free spin - 3000 psi. C 1.55 BPM - 1.52 to 1.62 BPM ~ 3280 to 3350 psi. - Up Wt. = 25,500, Dn Wt. = 16,000 - ROP at 20 - 80 fph. - Reactive torque inconsistant & problematic -difficult to set and maintain orientation. 04:00 - 06:00 2.00 DRILL P PROD1 Wiper Trip to Window. Tie in to RA Tag in Whipstock @ 9,668' per Geologist request +7 ft correction. 06:00 - 06:15 0.25 DRILL P PROD1 Orient high side. 06:15 - 10:30 4.25 DRILL P PRODi Dri11 to 11,100' MD -Free spin - 3000 psi. ~ 1.5 BPM - 1.5 / 1.6 BPM C~ 3300 to 3450 psi. - CT wt: 10k - Up Wt. = 25,500, Dn Wt. = 16,000 - ROP at 20 - 110 fph. 10:30 - 11:45 1.25 DRILL P PROD1 Wiper trip to window. 11:45 - 12:45 1.00 DRILL P PROD1 Drill to 11,250' MD. - Free spin - 3000 psi. C~ 1.5 BPM - 1.5 / 1.6 BPM ~ 3300 to 3450 psi. - CT wt: 9-10k - Up Wt. = 25,500, Dn Wt. = 16,000 - ROP at 80 - 110 fph. - Drilling at 170 ROHS - A little sticky off bottom, 10k overpull 12:45 - 13:15 0.50 DRILL P PROD1 Orient back down to 170 ROHS. 13:15 - 13:30 0.25 DRILL P PROD1 Drill to 11,395' MD -Free spin - 2800 psi. @ 1.57 BPM - 1.5 / 1.6 BPM C~ 3400 to 3600 psi. i I I Date !; From - To Hours Task Code I NPT Phase ? Description of Operations ~ _~ E 7/10/2005 15:00 - 16:00 1.00 DRILL P PRODi - 1.61 to 1.63 BPM C~? 3200 to 3600 psi. Printed: 7/18/2005 11:22:52 AM BP EXPLORATION Page 8 of 13 Operations Summary Report Legal Well Name: 15-31 Common Well Name: 15-31 Spud Date: 9/6/1992 Event Name: REENTER+COMPLETE Start: 6/28/2005 End: 7/17/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To Hours Task Code NPT Phase Description of Operations 7/11/2005 ~ 13:15 - 13:30 0.25~DRILL P ~ ~ PROD1 I - CT wt: 8-9k 13:30 - 13:45 0.25 DRILL P 13:45 - 14:00 0.25 DRILL P 7/12/2005 14:00 - 14:15 0.25 DRILL P 14:15 - 17:00 2.75 DRILL P 17:00 - 17:20 0.33 DRILL P 17:20 - 18:30.. 1.17 DRILL P 18:30 - 20:15 1.75 DRILL P 20:15 - 22:30 2.25 DRILL P PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PRODi 22:30 - 00:00 00:00 - 00:30 00:30 - 04:50 1.50 DRILL P 0.50 BRILL P 4.33 DRILL P PROD1 PROD1 PROD1 04:50 - 07:30 2.67 DRILL P PRODi 07:30 - 08:15 0.75 DRILL P PROD1 08:15 - 11:15 3.00 DRILL N DFAL PROD1 11:15 - 12:00 0.75 DRILL N 12:00 - 12:30 0.50 DRILL N 12:30 - 14:30 2.00 DRILL N 14:30 - 16:30 2.00 DRILL N DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PRODi - Up Wt. = 25,500, Dn Wt. = 15,500 - ROP at 80 - 110 fph. - Drilling at 170 ROHS Orienter flopped 180 deg. Orient around to 170 ROHS. Drill to 11137' MD. - Free spin - 3200 psi. ~ 1.5 BPM - 1.5 / 1.6 BPM C~ 3400 to 3600 psi. - CT wt: 8-9k - Swapping mud systems Orient TF to 90R. Drill to 11,206' MD -Free spin - 2800 psi. C~ i.5 BPM - 1.5 / 1.6 BPM C~3 3200 psi. - CT wt: 8-9k - TF "walking" Orient to 90R. Drill to 11,250' MD -Free spin -'2800 psi. ~ 1.5 BPM - 1.5 / 1.6 BPM C~ 3200 psi. - CT wt: 8-9k - TF "walking" Wiper trip to window. Drill to 11,395' MD -Free spin - 2800 psi. Cam? 1.5 BPM - 1.5 / 1.56 BPM C~? 3250 psi. - CT wt: 8-9k - TF 75 Left Wiper trip to window. Tie in to RA Tag in WS for depth control Tie in with GR: + 11 ft correction. RIH Drill to 11,501' MD -will not drill -bit balled? - Free spin - 2800 psi. C~ 1.5 BPM -Up Wt.=26.5 K, Dn. Wt.=14K - 1.5 / 1.56 BPM @ 3250 psi. - CT wt: 8-9k - TF walking Wper trip to 8000' MD. -Orient through shales at 9760' MD -- 90 ROHS. Attempt to get drilling, trying multiple tactics. No luck. Pressure decrease to 2000 psi. Suspect washout above MWD. Still getting signal. POOH with BHA. - Signs of packing off at 10,300' MD. - Pressure at 1700 psi, dropped to 1000 psi at 0.9 bpm. - Found leak in coil 9725' MD. (08:45 hrs) - Continue to POOH, pumps down. Lay down BHA. Circulate 15 bbls water in coil -Suck out sump. PJSM. Blow down reel with N2. - Continue to suck out sump. Cut off connector. PJSM. Unstab coil. Printed: 7/18/2005 11:22:52 AM BP EXPLORATION Page 9 of 13 Operations Summary Report Legal Well Name: 1 5-31 Common W ell Name: 1 5-31 Spud Date: 9/6/1992 Event Nam e: REENTE R+COM PLET E Start : 6/28/2005 End: 7/17/2005 Contractor Name: NORDIC CALIST A Rig Release: Rig Name: NORDIC 1 Rig Number: N1 ~ Date I i From - To I ~ Hours Task ~ i Code I NPT ~~ Phase ~ Description of Operations ~ ----- 7/12/2005 16:30 - 17:00 0.50 DRILL N DFAL PRODi PJSM for reel swap. 17:00 - 19:45 2.75 DRILL N DFAL PROD1 Swap reel. 19:45 - 22:30 2.75 DRILL N DFAL PRODi Re-connect coil through injector, Weld on CTC. Pump dart- 41.5 bbl displacement. 22:30 - 00:00 1.50 DRILL N DFAL PROD1 PU BHA. Test pulse at surface. No good. Run to 200'. No pulse. POOH. Change andlor test pulser assy. 7/13/2005 00:00 - 03:00 3.00 DRILL N DFAL PRODi Work with pulsor assy- bad battery. Replace battery. Positive test w/ pulsor. 03:00 - 06:45 3.75 DRILL N DFAL PROD1 RIH w/ CT and BHA. Intermittant communications w/ BHA. POOH to 1200'. Communicating. RIH to 2700' and test- working. RIH to 6000' and test- working. RIH to 9600' and test- working. Tie into window: +5' correction. RIH clean to bottom. 06:45 - 07:00 0.25 DRILL P PROD1 Orient to high side - Free spin at 2750 psi. 07:00 - 11:30 4.50 DRILL P PROD1 Drill ahead to 11,562' MD. - 1.5 / 1.6 bpm at 2850 - 3200 psi. -Drilling shale at 11,500' - CT wt 9k. - 25.5k PU; 14k SO. - 20-70 fph ROP - Considerable reactive torque. Orienting to keep tool face. 11:30 - 12:00 0.50 DRILL P PRODi Orient to drill at 90L. 12:00 - 12:45 0.75 DRILL P PROD1 Drill ahead to 11623' MD. - 1.5 / 1.6 bpm at 2850 - 3200 psi. - CT wt 9k. - 25.5k PU; 14k SO. - >100 fph ROP - TF walking up. 12:45 - 13:00 0.25 DRILL P PRODi Orient to drill at 90L f3:00 - 13:15 0.25 DRILL P PRODi Drill ahead 11,637' MD - 1.5 / 1.6 bpm at 2850 - 3200 psi. - CT wt 9k. - 25.5k PU; 14k SO. - >100 fph ROP 13:15 - 13:30 0.25 DRILL P PRODi Orient to 170 LOHS. - Entered sand, roll over to stay in sand. 13:30- 14:00 0.50 DRILL P PROD1 Drill ahead 11,670' MD - 1.51 1.6 bpm at 3300 psi. - CT wt 9k. - 25.5k PU; 14k SO. - >100 fph ROP 14:00 - 16:00 2.00 DRILL P PROD1 Wiper trip to window. - Motor work at 10,960' MD at RIH. 16:00 - 16:15 0.25 DRILL P PRODi Orient TF to 30L. 16:15 - 17:00 0.75 DRILL P PROD1 Drill ahead 11,750' MD - 1.5 / 1.55 bpm at 3200-3500 psi. - CT wt 4-6k. - 25.5k PU; 14k SO. - 50-100 fph ROP. Increased to >100 fph at 11,700. - Swapping to new mud. Drill solids nearing 1 % while drilling zone 1 A. 17:00 - 18:45 1.75 DRILL P PROD1 Orient TF to 170 ROHS. Drill ahead. 18:45 - 23:30 4.75 DRILL P PROD1 Perform wiper trip to 8000'. Correction at window: +6' Printed: 7/18/2005 11:22:52 AM • BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: 15-31 Common Well Name: 15-31 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date ~ From - To ; Hours ~ Task Code ii NPT 7/13/2005 ~ 23:30 - 00:00 ~ 0.50 ~ DRILL P 7/14/2005 100:00 - 02:00 I 2.001 DRILL I P 02:00 - 04:00 2.00 DRILL P 04:00 - 05:30 1.50 DRILL P 05:30 - 06:00 0.50 DRILL P 06:00 - 07:30 1.50 DRILL P 07:30 - 09:00 ~ 1.50 ~ DRILL ~ P 09:00 - 09:30 0.50 DRILL P 09:30 - 10:45 1.25 DRILL P 10:45 - 11:15 ~ 0.50 ~ DRILL ~ P 11:15 - 11:30 0.25 DRILL P 11:30 - 13:15 1.75 DRILL P 13:15 - 14:15 1.00 DRILL P 14:15 - 14:45 0.50 DRILL P 14:45 - 16:30 1.75 DRILL P 16:30 - 18:45 2.25 DRILL P 18:45 - 20:00 1.25 DRILL P 20:00 - 20:30 0.50 CASE P 20:30 - 21:00 0.50 CASE P 21:00 - 00:00 3.00 CASE P 7/15/2005 00:00 - 01:00 1.00 CASE P 01:00 - 04:30 3.50 CASE P 04:30 - 05:30 1.00 CASE P 05:30 - 07:00 1.50 CASE P 07:00 - 09:00 I 2.00) CEMT I P 09:00 - 09:45 0.75 CEMT P 09:45 - 10:00 0.25 CEMT P Spud Date: 9/6/1992 Start: 6/28/2005 End: 7/17/2005 Rig Release: Rig Number: N1 Phase Description of Operations I _ _ _ _ __ PROD1 Drill ahead from 11800' to 11852'. Free spin= 2900. 0= 1.55, 3200 press, 6000 WOB, 100'/hr. PROD1 Drill ahead from 11850' to 11967'. 0= 1.55, 3100 press, varying WOB, 140'/hr. Hold toolface. PROD1 Wiper trip to 9662'. PROD1 Drill ahead at 11967' to 12045'. 0=1.5, 3100 press, 5500 WOB, 150'/hr. PRODi Run 200' short trip to clear BHA- bit may be balling as well. PROD1 Attept to drill ahead. Drilling with negative weight. Drill to 12,055' MD - 1.43 / 1.5 bpm, 2800 psi free spin. -Difficult to get differential. PROD1 Wiper trip to window. - Discussed with Anchorage Asset team. Making slow footage at bottom. - Ream shale at 11,000 - 10,900' MD (faulted area). Overpulls of 20k, significant motor work. Did not wipe clean, will work more later if needed. PROD1 Tie in. +15' correction. PROD1 RIH to bottom, 12,062' MD. -Shales look good at 10,900 - 11,000' MD. - Hole in good condition. PROD1 Drill ahead to 12,105' MD. - 1.5 / 1.5 bpm at 2950 psi free spin -Drilling at 3700 psi, 60 - 150 fph. - Driliing with 7k CT wt. PROD1 Orient to 30 ROHS PROD1 Drill ahead to TD at 12210' MD. PRODi Wiper trip to window -final wiper. - Clean through fault. PROD1 Tie in. +3 ft correction. PROD1 Wipe back to bottom. - Stack up at 11,230' and 11,950' MD, fell through. - Pump liner pill. -Tag TD at 12,210' MD. PROD1 POOH, laying in liner pill. PRODi LD Drilling BHA RUNPRD Pump dart to establish coil vol: 39.6 bbl RUNPRD Conduct safety meeting RUNPRD Run and drift 2849' X 2.375" liner: Indexing Shoe, FC, 1 jt L80, FC, Pup Jt, LC, 56 jts L80, Pup, 33 jts L80, Pup jt, Deployment sleeve. RUNPRD Run and drift 2849' Liner and BHA. RUNPRD Connect Liner and coil. Wt: 28K# at window. RIH to bot. Bot. of liner: 12210, Top: 9338'. - Stack up at 11,520' MD. Circulate liner to bottom. RUNPRD Drop 5/8" ball and sting off of liner. RUNPRD Circulate 2% KCL and displace mud. - Losing approximately 0.1 bpm. RUNPRD Wait for cementers to get sleep. - Continue to circulate hole at 0.77 / 0.70 bpm. RUNPRD Rig up cementers. RUNPRD PJSM for cementing. Printed: 7/18(2005 11:22:52 AM ! ~ BP EXPLORATfON Page 11 of 13 Operations Summary Report Legal Well Name: 15-31 Common Well Name: 15-31 Spud Date: 9/6/1992 Event Name: REENTER+COMPLETE Start: 6/28/2005 End: 7/17/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To ~ Hours I Task Code NPT Phase 7/15/2005 10:00 - 10:15 0.25 CEMT P 10:15 - 11:15 I 1.001 CEMT I P 11:15 - 12:30 1.25 CEMT P 12:30 - 13:00 0.50 CEMT P 13:00 - 13:15 0.25 CEMT P 13:15 - 15:30 2.25 CEMT P 15:30 - 16:30 1.00 CEMT P 16:30 - 17:30 1.00 CEMT P 17:30 - 18:00 I 0.501 CEMT I P 18:00 - 19:30 1.50 CEMT P 19:30 - 23:30 4.00 CEMT P 23:30 - 00:00 0.50 CEMT P 7/16/2005 00:00 - 02:00 2.00 CEMT P 02:00 - 02:15 0.25 EVAL P 02:15 - 04:00 1.75 EVAL P 04:00 - 04:30 0.50 EVAL P 04:30 - 05:30 1.00 EVAL P 05:30 - 07:30 2.00 EVAL P 07:30 - 09:30 I 2.001 EVAL I P 09:30 - 11:00 I 1.501 EVAL f P 11:00 - 13:45 2.75 EVAL P 13:45 - 14:00 0.25 EVAL P 14:00 - 15:00 1.00 CEMT P 15:00 - 16:15 ~ 1.25 ~ CEMT ~ P RUNPRD ~ Batch up cement Description of Operations Pressure test lines to 4000 psi. RUNPRD Pump cement. -Zero MM at 15.8 ppg density. - Pump 14.9 bbl cement at 1.42 / 1.28 bpm. - Clear lines. Zero in MM. - Launch dart. - Follow with 30 bbls bio. - Zero out MM with cement at shoe. - Slow pumps at 38 bbls away, latch up at 39.3 bbls. - Shear LWP at 3000 psi. - Pump cement at 1.5 / 1.1 bpm, decrease pump rate to 1.1 / 1.1 bpm at 2600 psi. -Bump plug at 49.8 bbls (predicted at 50.62). - 13.2 bbls cement in annulus. - Pressure up 600 psi. Bleed off, check floats. - Unsting. RUNPRD POOH with CTLRT. RUNPRD Lay down BHA. - RUNPRD PJSM for PU CSH. RUNPRD PU 97 joints CHS, motor, 1.875" mill cleanout assy. RUNPRD RIH with cleanout assy. RUNPRD cleanout 2-3/8" liner. - No WOC time. Cement at 500 psi compressive strength. - 0.8 / 0.8 bpm at 1900 psi. - No hard cement found. RUNPRD POOH from liner at 10770' MD at 50 fpm, pumping minimum rate. - Error from SLB Cement Lab. Fax sent in from lab, though labeled with our rig and well information, was not for our job. - POOH to safety to continue to WOC until our cement is at 500 psi compressive strength. RUNPRD Wait on cement. RUNPRD Clean out well to 12170' (PB). No probs. POOH. RUNPRD Hold PJSM with crew. Begin standing Back 97 jts CS Hydril. RUNPRD Stand back 97 jts. CSH LOWERI Condcuct PJSM over logging. LOWERi RIH w/ logging assy LOWERI RU Injector, connect coil to logging assy LOWERI RIH w/ logging assy and coil to 8800' LOWERI Log down from 8800' to TD at 30 fpm. - 1.03 / 1.19 bpm at 2550 psi. - Circulate pill down. LOWERI POOH, logging at 60 fpm. - Lay in pert pill LOWERi POOH with logging BHA. - Circulating out bio. LOWERI Stand back 16 stands CSH, lay out 65 joints. LOWERI PJSM. Lay out MCNL logging tool. RUNPRD MU nozzle. Jet stack. LD nozzle. - Load guns. RUNPRD Pressure test liner lap to 2000 psi for 30 minutes. Chased surface leaks/bleedoff. Printed: 7/18/2005 11:22:52 AM ~ ~ U BP EXPLORATfON Page 12 of 13 Operations Summary Report ..Legal Well Name: 15-31 Common Well Name: 15-31 Spud Date: 9/6/1992 Event Name: REENTER+COMPLETE Start: 6/28/2005 End: 7/17/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date i From -Too HHours Task Code NPT Phase Description of Operations 7/16/2005 15:00 - 16:15 I 1.25 ~ CEMT ~ P ~ RUNPRD Time Pressure Delta 0 1950 5 1820 130 10 1730 90 15 1670 60 Leakoff getting better. Try again. Time Pressure Delta 0 2010 5 1850 160 10 1780 70 15 1725 55 20 1680 45 25 1635 45 30 1600 35 35 1570 30 Bled off 280 psi in 30 minutes = 15% decline from 1850 psi to 1570 psi. If using the first 5 minutes, bled off 410 psi in 30 minutes = 20°f° decline from 20i 0 pis to 1600 psi. Discussed with Anchorage Team, no liner top packer required. 16:15 - 16:45 0.50 PERFO P LOWERI PJSM. MU safety joint. 16:45 - 22:00 5.25 PERFO P LOWERI PU 87 pert guns. Conducted PJSM at 1830 hrs for crew change. - 401oaded - 11 partials - 36 blanks - 17.5 Stds of CSH 22:00 - 23:30 1.50 PERFO P LOWERi RIH to bot (12173'). 23:30 - 00:00 0.50 PERFO P LOWERi Drop 1/2" ball. Slowly PU pipe. Guns detonate at 2600 psi. 7/17/2005 00:00 - 00:30 0.50 PERFO LOW ER1 Pumping .65 bpm (pert pill). Chase ball with remainder of pert pill. Detonate guns while slowly PU. No drag. POOH. 00:30 - 02:30 2.00 PERFO LOWERI POOH - 30 minute flow check at TOL. 02:30 - 09:30 7.00 PERFO LOWERI Disconnect from coil, Conduct PJSM, LD CSH, spent guns. 09:30 - 10:00 0.50 PERFO LOWERI Rig down pert equipment. Unload guns. MU nozzle. 10:00 - 11:30 1.50 WHSUR POST R{H with nozzle to 2500'. Freeze protect while POOH. 11:30 - 15:30 4.00 WHSUR POST Wait for N2 pumpers to get required sleep. - Clean pits. - Continue outside work on rig. - Master and Swab closed. - Mix corrosion inhibitor pill. 16:00 - 16:30 0.50 WHSUR POST Pump 40 bbls fresh water. Pump 5 bbls fresh water with 25 gallons corrosion inhibitor. Pump 10 bbls fresh water. Pump 5 bbls MEOH. 16:30 - 16:45 0.25 WHSUR POST N2 arrived. Cooling down. 16:45 - 17:45 1.00 WHSUR POST Blow down with N2. 17:45 - 19:00 1.25 RIGD POST Gut CTC. Unstab coil. Secure to reel. 19:00 - 22:00 3.00 RIGD POST ND BOP stack. Installed tree cap. Printed: 7/18/2005 11:22:52 AM Printed: 7/18/2005 11:22:52 AM i • Halliburton Global '~ Company: BP Amoco Date: 813!2005 Time: 16:11:05 Page: ] Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-31, True N orth Site: PB DS 15 Vertical (TVD) Refer ence: 45:31 9/6/1992 OO :OQ 64.6 Well: 1'5-31 Section (VS) Referen ce: Well (O.OON,O.OOE,1 12.49Azi) Wellpath: 15-31 B Snrvcy CalculationD lcthod: Minimum Curvature Db: Oracle -- Field: Prudhoe Bay - _ _. _ __ -- - -- - North Slope UNITED STATES Map System:US State Plane Coordinate System 19 27 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 {Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: 15-31 Slot Name: 15-31 Well Position: +N/-S 714.57 ft Northing: 5959577.69 ft Latitude: 70 17 42.263 N +E/-W 1108.94 ft Easting : 677388.79 ft Longitude: 148 33 48.892 W Position Uncertainty: 0.00 ft Wellpath: 15-31 B Drilled From: 15-31 500292228502 Tie-on Depth: 9544.85 ft Current Datum: 45:31 9/6/1992 00 :00 Height 64.60 ft Above System Datum: Mean Sea Level Magnetic Data: 5/2/2005 Declination: 24.99 deg Field Strength: 57606 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33. 60 0.00 0.00 112.49 Survey Program for Definitive Wellpath Date: 7/18/2005 Validated: Yes Version: 4 Actual From To Survey Toolcode Tool Name ft ft 432.24 9544.85 1 : MWD -Standard (432 .24-11762.07) (0) MWD MWD -Standard 9636.19 12210.00 MWD (9636.19-12210.00) MWD MWD -Standard Survey ~4D Inc! ~zim 1~'D Sys'1'VD N!S E/~1 ~7apN J1apN~ Tool ft deg deg ft ft ft ft ft ft 33.60 0.00 0.00 33.60 -31.00 0.00 0.00 5959577.69 677388.79 TIE LINE 432.24 0.22 298.95 432.24 367.64 0.37 -0.67 5959578.04 677388.11 MWD 905.03 0.45 45.18 905.02 840.42 2.12 -0.15 5959579.80 677388.59 MWD 1405.15 0.49 22.16 1405.13 1340.53 5.48 2.05 5959583.22 677390.71 MWD 1910.78 0.37 71.39 1910.74 1846.14 8.01 4.42 5959585.80 677393.01 MWD 2419.88 1.15 99.94 2419.80 2355.20 7.65 11.01 5959585.60 677399.61 MWD 2925.23 1.81 145.14 2924.99 2860.39 0.23 20.56 5959578.40 677409.34 MWD 3468.55 1.58 162.25 3468.08 3403.48 -13.95 27.75 5959564.40 677416.86 MWD 3820.28 0.89 155.74 3819.72 3755.12 -21.06 30.35 5959557.36 677419.63 MWD 4129.69 0.57 155.56 4129.11 4064.51 -24.65 31.98 5959553.80 677421.34 MWD 4454.41 0.61 160.88 4453.81 4389.21 -27.75 33.21 5959550.73 677422.64 MWD 4671.41 0.24 146.99 4670.80 4606.20 -29.23 33.84 5959549.27 677423.30 MWD 4778.87 1.06 156.96 4778.26 4713.66 -30.33 34.35 5959548.18 677423.84 MWD 4874.93 2.21 120.10 4874.28 4809.68 -32.08 36.30 5959546.48 677425.83 MWD 4969.06 3.64 112.15 4968.28 4903.68 -34.11 40.64 5959544.55 677430.22 MWD 5063.49 4.58 106.63 5062.47 4997.87 -36.32 47.02 5959542.49 677436.66 MWD 5158.75 5.43 106.15 5157.37 5092.77 -38.66 55.00 5959540.34 677444.68 MWD 5253.92 6.61 100.08 5252.01 5187.41 -40.88 64.72 5959538.36 677454.45 MWD 5349.11 7.51 95.33 5346.48 5281.88 -42.41 76.31 5959537.09 677466.07 MWD 5444.21 8.27 98.62 5440.68 5376.08 -44.02 89.26 5959535.80 677479.05 MWD 5539.63 8.96 98.41 5535.02 5470.42 -46.13 103.39 5959534.02 677493.23 MWD 5635.07 10.75 93.76 5629.05 5564.45 -47.80 119.63 5959532.73 677509.50 MWD 5730.60 12.08 94.72 5722.69 5658.09 -49.21 138.48 5959531.77 677528.38 MWD 5822.90 13.65 95.74 5812.67 5748.07 -51.09 158.94 5959530.37 677548.88 MWD 5913.74 15.00 94.81 5900.68 5836.08 -53.15 181.32 5959528.84 677571.31 MWD 6004.33 16.55 94.64 5987.86 5923.26 -55.18 205.87 5959527.39 677595.89 MWD 6094.52 17.97 96.21 6073.98 6009.38 -57.72 232.50 5959525.48 677622.58 MWD 6183.00 19.04 96.12 6157.89 6093.29 -60.74 260.42 5959523.12 677650.56 MWD 6278.23 20.87 96.35 6247.40 6182.80 -64.27 292.73 5959520.35 677682.94 MWD • • Halhburton Global Company: Field: Site: Well: ~Vellpath: Survey MD ft BP Amoco Prudhoe Bay PB DS 15 15-31 15-31 B lncl deg zim deg VD ft ys1'VD ft Date: 8/3/2005 Timr. 16:11:05 Page: 2 Co-ordinate(NE) Reference: Well: 15-31, True North Vertical (TVD) Reference: 45:31 9/6/1992 00:00 64.6 Section (VS) Reference: Well (O.OON,O.OOE,112.49Azi) Survey Calculafiou D~lethod: Minimum Curvature llb: Oracle N/S E/~'V Maps MapE Ton ft ft ft ft 6369. 31 22. 33 94 .42 6332. 08 6267 .48 -67. 40 326. 11 5959518 .01 677716 .37 MWD 6461. 42 23. 66 95 .99 6416. 87 6352 .27 -70. 67 361. 94 5959515 .58 677752 .27 MWD 6553. 86 24. 70 96 .03 6501. 20 6436 .60 -74. 64 399. 59 5959512 .51 677790 .01 MWD 6645. 91 25. 93 97 .54 6584. 41 6519 .81 -79. 30 438. 67 5959508 .77 677829 .18 MWD 6738. 37 27. 00 97 .17 6667. 18 6602 .58 -84. 57 479. 54 5959504 .46 677870 .16 MWD 6828. 76 27. 81 96 .80 6747. 42 6682 .82 -89. 63 520. 83 5959500 .38 677911 .56 MWD 6920. 75 28. 67 96 .97 6828. 46 6763 .86 -94. 85 564. 04 5959496 .18 677954 .88 MWD 7009. 12 29. 02 98 .50 6905. 87 6841 .27 -100. 59 606. 28 5959491 .44 677997 .24 MWD 7103. 63 29. 29 97 .70 6988. 41 6923 .81 -107. 08 651. 87 5959486 .03 678042 .96 MWD 7196. 18 29. 46 98 .28 7069. 06 7004 .46 -113. 39 696. 82 5959480 .79 678088 .05 MWD 7376. 82 31. 15 97 .76 7225. 01 7160 .41 -126. 09 787. 08 5959470 .21 678178 .58 MWD 7554. 16 34. 92 94 .60 7373. 66 7309 .06 -136. 36 883. 16 5959462 .22 678274 .87 MWD 7738. 37 36. 41 99 .38 7523. 35 7458 .75 -149. 50 989. 68 5959451 .59 678381 .66 MWD 7953. 56 41. 85 100 .55 7690. 21 7625 .61 -173. 07 1123. 37 5959431 .19 678515 .86 MWD 8166. 66 46. 09 98 .26 7843. 56 7778 .96 -197. 13 1269. 30 5959410 .58 678662 .30 MWD 8351. 73 49. 64 97 .05 7967. 70 7903 .10 -215. 37 1405. 29 5959395 .56 678798 .69 MWD 8596. 65 55. 16 98 .89 8117. 09 8052 .49 -242. 38 1597. 36 5959373 .09 678991 .33 MWD 8780. 89 53. 36 107 .50 8224. 83 8160 .23 -276. 33 1742. 75 5959342 .58 679137 .46 MWD 8885. 39 54. 98 109 .68 8286. 01 8221 .41 -303. 35 1823. 04 5959317 .46 679218 .36 MWD 8963. 98 56. 28 107 .41 8330. 38 8265 .78 -323. 97 1884. 53 5959298 .30 679280 .32 MWD 9055. 78 57. 51 106 .94 8380. 51 8315 .91 -346. 68 1958. 00 5959277 .34 679354 .30 MWD 9149. 48 62. 09 101 .31 8427. 66 8363 .06 -366. 33 2036. 49 5959259 .54 679433 .23 MWD 9242. 40 63. 49 97 .81 8470. 16 8405 .56 -380. 04 2117. 96 5959247 .76 679514 .99 MWD 9333. 64 66. 69 99 .58 8508. 59 8443 .99 -392. 56 2199. 75 5959237 .17 679597 .05 MWD 9454. 24 68. 47 101 .20 8554. 58 8489 .98 -412. 68 2309. 39 5959219 .65 679707 .13 MWD 9544. 85 69. 29 98 .74 8587. 24 8522 .64 -427. 30 2392. 63 5959207 .00 679790 .68 MWD 9636. 19 69. 90 99 .31 8619. 08 8554 .48 -440. 73 2477. 18 5959195 .57 679875 .52 MWD 9662. 30 70. 08 99 .25 8628. 02 8563 .42 -444. 69 2501. 39 5959192 .18 679899 .82 MWD 9671. 69 65. 30 99 .45 8631. 58 8566 .98 -446. 10 2509. 96 5959190 .98 679908 .42 MWD 9700. 35 64. 86 104 .30 8643. 66 8579 .06 -451. 45 2535. 38 5959186 .23 679933 .96 MWD 9731. 35 65. 34 109 .57 8656. 72 8592 .12 -459. 63 2562. 27 5959178 .68 679961 .03 MWD 9762. 02 66. 09 117 .74 8669. 35 8604 .75 -470. 84 2587. 85 5959168 .08 679986 .86 MWD 9792. 21 68. 29 121 .96 8681. 06 8616 .46 -484. 70 2611. 97 5959154 .80 680011 .30 MWD 9821. 95 66. 44 126 .00 8692. 51 8627 .91 -500. 03 2634. 73 5959140 .01 680034 .42 MWD 9851. 31 65. 72 120 .97 8704. 42 8639 .82 -514. 83 2657. 10 5959125 .74 680057 .13 MWD 9883. 96 70. 31 119 .50 8716. 64 8652 .04 -530. 07 2683. 25 5959111 .13 680083 .63 MWD 9912. 62 72. 56 116 .28 8725. 77 8661 .17 -542. 77 2707. 26 5959099 .00 680107 .93 MWD 9939. 88 71. 00 112 .61 8734. 29 8669 .69 -553. 48 2730. 83 5959088 .84 680131 .74 MWD 9970. 82 71. 02 106 .67 8744. 37 8679 .77 -563. 31 2758. 37 5959079 .67 680159 .51 MWD 10001. 05 70. 75 101 .39 8754. 28 8689 .68 -570. 24 2786. 07 5959073 .40 680187 .36 MWD 10034. 49 71. 81 97 .00 8765. 01 8700 .41 -575. 29 2817. 32 5959069 .08 680218 .72 MWD 10063. 84 75. 67 99 .29 8773. 23 8708 .63 -579. 29 2845. 20 5959065 .75 680246 .69 MWD 10096. 13 76. 64 105 .61 8780. 96 8716 .36 -586. 05 2875. 80 5959059 .71 680277 .44 MWD 10127. 11 75. 76 111 .24 8788. 36 8723 .76 -595. 55 2904. 33 5959050 .89 680306 .18 MWD 10160. 96 72. 69 117 .15 8797. 57 8732 .97 -608. 88 2934. 03 5959038 .26 680336 .19 MWD 10191. 43 74. 36 122 .36 8806. 22 8741 .62 -623. 38 2959. 39 5959024 .37 680361 .87 MWD 10220. 78 74. 35 129 .87 8814. 14 8749 .54 -640. 02 2982. 20 5959008 .26 680385 .07 MWD 10251. 27 74. 44 135 .14 8822. 35 8757 .75 -659. 86 3003. 84 5958988 .95 680407 .17 MWD 10283. 10 76. 33 137 .86 8830. 38 8765 .78 -682. 20 3025. 03 5958967 .12 680428 .89 MWD 10314. 77 83. 58 137 .78 8835. 90 8771 .30 -705. 29 3045. 96 5958944 .52 680450 .35 MWD 10345. 81 87. 54 141 .82 8838. 30 8773 .70 -728. 92 3065. 92 5958921 .37 680470 .87 MWD 10367. 01 88. 18 142 .23 8839. 10 8774 .50 -745. 62 3078. 96 5958904 .99 680484 .29 MWD Halhburton Global Company: BP Amoco Date: 8/3/2005 Time: 16:11:05 Page: 3 Field: Pru dhoe Bay Co-ord inate(NE) Re ference: Well: 15-31, True N orth Sitr. PB DS 15 Vertical (TVD) Refe rence: 45 :31 9/6/1992 00 :00 64.6 Well: 15- 31 Section (VS) Refere nce: Well (O.OON,O. OOE, 112.49Azi) I yVellpath: 15- 31 B Survey Calcula tion Dlethod: Minimum Curv ature Db: Oracle Surccy -- -_ MD incl Azim 'I'Vll Sys "1'V D N/S E/W AtapN MapE Tool ft deg deg ft ft ft ft ft ft 10402. 32 88. 60 141. 19 8840. 09 8775 .49 -773. 32 3100. 83 5958877 .81 680506. 81 MWD 10435. 46 90. 88 138. 48 8840. 24 8775 .64 -798. 64 3122. 20 5958853 .00 680528. 77 MWD 10464. 09 92. 20 137. 61 8839. 47 8774 .87 -819 .93 3141. 33 5958832 .18 680548. 40 MWD 10488. 67 90. 70 131. 63 8838. 85 8774 .25 -837 .18 3158. 82 5958815 .35 680566. 28 MWD 10516. 30 87. 63 127. 94 8839. 25 8774 .65 -854 .85 3180. 04 5958798 .18 680587. 91 MWD 10550. 38 87. 10 122. 66 8840. 82 8776 .22 -874. 52 3207. 81 5958779 .18 680616. 14 MWD 10571. 38 88. 15 121. 79 8841. 69 8777 .09 -885. 70 3225. 56 5958768 .41 680634. 15 MWD 10606. 49 89. 30 116. 51 8842. 47 8777 .87 -902. 80 3256. 21 5958752 .05 680665. 19 MWD 10640. 17 90. 19 114. 96 8842. 62 8778 .02 -917. 42 3286. 55 5958738 .15 680695. 86 MWD 10672. 34 91. 67 110. 89 8842. 10 8777 .50 -929. 95 3316. 16 5958726 .32 680725. 76 MWD 10702. 28 92. 20 108. 25 8841. 09 8776 .49 -939. 97 3344. 36 5958716 .97 680754. 18 MWD 10738. 85 90. 88 102. 45 8840. 10 8775 .50 -949. 64 3379. 59 5958708 .13 680789. 64 MWD 10783. 75 89. 04 103. 51 8840. 13 8775 .53 -959. 72 3423. 34 5958699 .08 680833. 61 MWD 10812. 17 89. 03 109. 31 8840. 61 8776 .01 -967. 75 3450. 59 5958691 .70 680861. 04 MWD 10845. 30 88. 86 116. 86 8841. 22 8776 .62 -980. 73 3481. 04 5958679 .45 680891. 78 MWD 10873. 99 87. 89 119. 68 8842. 04 8777 .44 -994. 31 3506. 30 5958666 .47 680917. 35 MWD 10902. 74 89. 57 124. 39 8842. 67 8778 .07 -1009. 55 3530. 65 5958651 .81 680942. 06 MWD 10940. 82 90. 40 127. 07 8842. 68 8778 .08 -1031. 79 3561. 56 5958630 .31 680973. 48 MWD 10972. 44 92. 55 125. 65 8841. 87 8777 .27 -1050. 52 3587. 02 5958612 .18 680999. 37 MWD 11004. 54 96. 50 125. 65 8839. 34 8774 .74 -1069. 17 3613. 01 5958594 .15 681025. 80 MWD 11038. 17 100. 36 126. 74 8834. 41 8769 .81 -1088. 81 3639. 86 5958575 :15 681053. 09 MWD 11071. 59 98. 09 128. 64 8829. 05 8764 .45 -1108. 98 3665. 96 5958555 .61 681079. 66 MWD 11099. 38 95. 54 129. 70 8825. 75 8761 .15 -1126. 41 3687. 35 5958538 .69 681101. 45 MWD 11136. 64 91. 85 138. 31 8823. 35 8758 .75 -1152. 21 3714. 06 5958513 .52 681128. 76 MWD 11161. 41 92. 90 134. 27 8822. 32 8757 .72 -1170. 10 3731. 15 5958496 .05 681146. 28 MWD 11195. 37 88. 07 139. 19 8822. 03 8757 .43 -1194. 81 3754. 42 5958471 .89 681170. 12 MWD 11231. 15 87. 10 140. 95 8823. 54 8758 .94 -1222. 22 3777. 36 5958445 .03 681193. 70 MWD 11262. 06 87. 10 146. 04 8825. 11 8760 .51 -1247. 03 3795. 72 5958420 .67 681212. 64 MWD 11292. 12 88. 77 150. 97 8826. 19 8761 .59 -1272. 63 3811. 41 5958395 .44 681228. 92 MWD 11333. 08 85. 25 146. 75 8828. 33 8763 .73 -1307. 63 3832. 55 5958360 .95 681250. 88 MWD 11364. 52 86. 40 143. 93 8830. 62 8766 .02 -1333. 42 3850. 38 5958335 .59 681269. 32 MWD 11401. 54 88. 15 137. 08 8832. 38 8767 .78 -1361. 94 3873. 89 5958307 .64 681293. 49 MWD 11443. 24 87. 54 134. 97 8833. 95 8769 .35 -1391. 92 3902. 82 5958278 .35 681323. 12 MWD 11480. 90 86. 13 137. 43 8836. 03 8771 .43 -1419. 06 3928. 84 5958251 .84 681349. 77 MWD 11508. 12 88. 51 136. 20 8837. 30 8772 .70 -1438. 88 3947. 45 5958232 .46 681368. 84 MWD 11538. 00 93. 69 132. 68 8836. 73 8772 .13 -1459. 79 3968. 77 5958212 .06 681390. 65 MWD 11569. 51 93. 78 134. 62 8834. 67 8770 .07 -1481. 49 3991. 52 5958190 .90 681413. 90 MWD 11602. 11 96. 66 126. 48 8831. 70 8767 .10 -1502. 58 4016. 16 5958170 .40 681439. 03 MWD 11638. 05 95. 97 123. 66 8827. 75 8763 .15 -1523. 10 4045. 39 5958150 .58 681468. 74 MWD 11668. 61 91. 58 123. 37 8825. 74 8761 .14 -1539. 94 4070. 81 5958134 .35 681494. 54 MWD 11705. 70 96. 77 120. 56 8823. 04 8758 .44 -1559. 52 4102. 18 5958115 .52 681526. 36 MWD 11747. 20 97. 12 114. 75 8818. 02 8753 .42 -1578. 63 4138. 65 5958097 .27 681563. 27 MWD 11789. 73 94. 31 109. 31 8813. 78 8749 .18 -1594. 49 4177. 86 5958082 .34 681602. 85 MWD 11818. 69 92. 90 111. 41 8811. 96 8747 .36 -1604. 54 4204. 95 5958072 .93 681630. 17 MWD 11852. 26 92. 81 118. 62 8810. 28 8745 .68 -1618. 71 4235. 32 5958059 .48 681660. 86 MWD 11887. 97 95. 27 127. 76 8807. 76 8743 .16 -1638. 19 4265. 10 5958040 .72 681691. 08 MWD 11921. 31 95. 18 134. 62 8804. 72 8740 .12 -1660. 04 4290. 07 5958019 .46 681716. 56 MWD 11951. 90 91. 32 136. 90 8802. 99 8738 .39 -1681. 91 4311. 37 5957998 .10 681738. 37 MWD 11990. 01 89. 03 132. 51 8802. 87 8738 .27 -1708. 71 4338. 44 5957971 .95 681766. 07 MWD 12021. 66 89. 56 129. 17 8803. 26 8738 .66 -1729. 41 4362. 38 5957951 .83 681790. 49 MWD 12050. 82 89. 47 126. 18 8803. 51 8738 .91 -1747. 23 4385. 46 5957934 .56 681813. 98 MWD 12079. 61 87. 65 128. 96 8804. 23 8739 .63 -1764. 77 4408. 27 5957917 .56 681837. 20 MWD 12102. 40 84. 81 137. 61 8805. 73 8741 .13 -1780. 35 4424. 81 5957902 .38 681854. 10 MWD • Halli • burton Global Company: BP Amoco Date: 8/3/2005 Time: 16:11:05 Page: 4 Field: Prudhoe Bay Co-ordinate(VE) Reference: Well: 15-31, True North Sitc: PB DS 15 Vertical (TVD) Reference: 45:31 9/6/1992 00:00 64.6 ~i ~4'cll: 15-31 Section (VS) Reference: Well (O.OON,O.OOE,112.49Azi) Wellpath: 15-31 B Surrey Calculation ~~lethod: Minimum Curvature DU: Oracle Sur~c~' - iVIU Incl .1zim TVD - Svs'1-VD - _ -- - - VIS E/W DtapN D1apE 'I'dol ft deg deg ft ft ft ft ft ft 12136.94 89.65 137.08 8807.40 8742.80 -1805.71 4448.18 .5957877.57 681878.06 MWD 12163.37 94.66 138.84 8806.41 8741.81 -1825.32 4465.86 5957858.39 681896.19 MWD 12192.65 96.77 141.12 8803.49 8738.89 -1847.63 4484.59 5957836.53 681915.45 MWD 12210.00 96.77 141.12 8801.45 8736.85 -1861.04 4495.41 5957823.38 681926.57 MWD TREE = FMC WELLHEAD = CNV ACTUATOR = _ AXELSON KB. ELEV = 64.6' BF. ELEV = _ KOP = 5540' Max Angle = 95 @ 11219' Datum MD = WA Datum ND = 8800' SS 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 13-3/8" CSG, 68#, L-80, ID = 12.415" TOP OF 7" LNR 9-5/8" CSG, 47#, NT-80S, ID = 8.681" I 2926' I I 8962' I PERFORATION SUMMARY REF LOG: SPERRY MWD GR/DENS/NEUT ON 09/27/92 ANGLE AT TOP PERF: 88 @ 10340' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 10825 - 11150 isolated 07/15/05 1-11/16" 4 11300 - 11875 isolated 07/15/05 1-11/16" 4 11950 - 12120 isolated 07/15/05 1.56" 6 10600 - 10640 isolated 07/15/05 1.56" 6 10665 - 10685 isolated 07/15/05 1.56" 6 10340-10450 Open 07/17/05 1.56" 6 10490-10580 Open 07/17/05 1.56" 6 10650-10840 Open 07/17/05 1.56" 6 11230-11280 Open 07/17/05 1.56" 6 11320-11460 Open 07/17/05 1.56" 6 11720-11770 Open 07/17/05 1.56" 6 11890-12170 Open 07/17/05 TBG PUNCH (05/30/02) ~-i 10000'-10010' ITOPOF WHIPSTOCK 1~ 10106' i3-1/2" TBG, 9.2#, L-80, TDS, 0.00868bpf, ID = 2.990" ~ 10766' 2-3/8" TBG, 4.7#, L-80, .00387 bpf, ID = 1.995" 12178' 7" LNR, 27#, NT-80S, NSCC, 0.0383 bpf, ID = 6.276" 11084' I ~4-1/2" LNR-SLTD, 12.63#, L-80, ~ 11728' J FL4S, 0.0152 bpf, ID = 3.958" ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3188 3188 1 CA-MMG-2 DMY RK 0 04/17/04 2 5497 5493 8 CA-MMG-2 DMY RK 0 04/17/04 3 6970 6872 28 CA-MMG-2 DMY RK 0 4 8377 7984 50 CA-MMG-2 DMY RK 0 5 8503 8062 55 CA-MMG-2 DMY RK 0 9031' --I 3-1/2" PARKER SWS NIP, ID = 2.813" 9050' 3-1/2" X 4-1/2" XO 9053' 7" X 4-1/2" BAKER SABL-3 PKR 9057' 4-1 /2" X 3-1 /2" x01 9071' 3-1/2" PARKER SWS NIP, ID = 2.813" 9336' 2-3/8" Lnr, 4.7#, L-80, .00387 bpf, ID 1.995" 9336' -~ Top of Cement ~ 9502-07 Tubing Punch? 2-3/8" cemented, PBTD ~-1 12175' 9662' Top of Whipstock 9656-81 Perfs 9765' CIBP 9816-21 Tubing Punch? 9833' KB LNR TOP PKR, ID = 1.75" 9857' 3" BKR DEPLOYMENT SLV, ID = 2.700" 9863' 2-3/4" X 2-3/8" XO, ID =~ 1 ~~995"1- DATE REV BY COMMENTS DATE REV BY COMMENTS 10/01/92 ORIGINAL COMPLETION 09/12/03 CMO/TLP DATUM MD& PERFANGLE/REF 09/01/93 LAST WORKOVER 11/29/03 BJMcM/TL LNR TOPPKR, TBG ID/BPF 06/16/02 JDMIKK CTD SIDETRACK 12/04/03 MCL/TLP PERFS 06124!02 JNVKAK GLV GO 04/17/04 JLJIKAK GLV GO 08/15/02 GGKAK MIN ID CORRECTION 06/16/05 MSE PROPOSED CTD SIDETRACK 06/13/03 CMO/TLP KB ELEVATION CORRECTION 07/17/05 BMH CTD Side Track PRUDHOE BAY UNIT WELL: 15-31 B PERMIT No: API No: 50-029-22285-02 SEC 22, T11 N, R14E, 4597.85' FEL & 2653.89' FNL BP Exploration (Alaska) 15-31B CTD Sidetrack 2078' 4-1/2" CAMCO TRDP-4A-SC O SSSV NIP, ID = 3.812" 2926' 4-1/2" X 3-1/2" XO GAS LIFT MANDRELS • • ~ ~~ ~ ~ ~ ~ "°~ ~ ~ s ~ ~ ? FRANK H. MURKOWSK/, GOVERNOR f ~'~ ~ ~ ~ ~+ ~ t~~ ~r ~ ~+ ~I~-7~~~T O~ t>•isil Vro~7 a'I 333 W. T" AVENUE, SUITE 100 CO~SERQAiiO1s CO~~IISSIO~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 15-31B BP Exploration (Alaska) Inc. Permit No: 205-086 Surface Location: 1937' FNL, 1438' FWL, SEC. 22, T11N, R14E, UM Bottomhole Location: 3678' FNL, 552' FWL, SEC. 23, T11N, R14E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to itr}ess any required test. Contact the Commission's petroleum field inspector at ~~j~59- O ger). DATED this day of June, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1~[~rh~ ~l~rLaeS STATE OF ALASKA ~ ~ ~ ~ , ALAS OIL AND GAS CONSERVATION MMISSION ~~ ~ ~.. ~ ' PERMIT TO DRILL r~~y ~ ~~ ~~~~~ ~ 20 AAC 25.005 / 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Devetdj3fttAn i - I~'itlPSl ^ Stratigraphic Test ^ Service ^ Development Gas %~ one 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number: 15-31 B ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12050 TVD 8732ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface. ~, 1937'$NL 1438'./?WL SEC T11N R14E 22 UM 7. Property Designation: ADL 028307 Pool , , . , , , Top of Productive Horizon: 2454' SNL, 4415' EWL, SEC. 22, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: June 13, 2005 Total Depth: 3678' S~NL, 552' f4WL, SEC. 23, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 29,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 677389 y- 5959578 Zone- ASP4 10. KB Elevation (Height above GL): 64.6' feet 15. Distance to Nearest Well Within Pool 48' to 15-25A at 10110' MD 16. Deviated Wells: Kickoff Depth: 9650 feet Maximum Hole Angle: 93 de rees 17. Maximum Anticipated Pressures in prig (see 20 AAC 25.035) Downhole: 3285 Surface: 2400 ~ 18. asing Program: Size Specifications Setting Depth To Bottom uantlty o ement c.f or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 2950' 9100' 8339' 12050' 8732' 3 cu ft Class 'G' ' 19. PRESENT WELL CONDITION SUMMARY (To be completed for RedrilfAND Re-entry Operations) Total Depth MD (ft): 12214 Total Depth TVD (ft): 8786 Plugs (measured): None Effective Depth MD (ft): 12140 Effective Depth TVD (ft): 8783 Junk (measured): None Casin Len th Size Cement Volume MD TVD r Con r 110' 20" 000# Coldset II 110' 110' rf 3488' 13-3/8" 554 cu ft CS III, 460 cu ft Class 'G' 3524' 3524' I 8920' 9-5/8" 1644 cu ft Class 'G', 506 cu ft Class 'G' 8952' 8324' Pr ion 1468' 7" 93 cu ft Class 'G' 8651' - 10119' 8148' - 8762' Liner 2344' 2-3/8" 112 cu ft Class 'G' 9834' - 12178' 8685' - 8785' Perforation Depth MD (ft): 10600' - 12120' Perforation Depth TVD (ft): 8814' - 8782' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mary Endacott, 564-4388 Printed Name Mary Endacott Title CT Drilling Engineer ~f Prepared By Name/Number: Si nature ~ ` >~ Phone 564-4388 Date ~ ~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: Zo„'-~ ~ API Number: 50- 029-22285-02-00 Permit Approval Date: ~ ~ p See cover letter for other requirements Conditions of Approval: Sa le Required h Yes ', ~ No Mud Log Required ^ Yes j~No drog n Sulfide Measures ~ Yes ~ No Directional Survey Required es ^ No Other: TC'S ~ ~ _ ~ ,~5%3C) ~ ~}. A rov ~ ~ ~ ~~ ~ THE OMMISSION Date 6 n Form 10-401 ~ed /2 4 ~~ Submit' In Duplicate gp 15-31B Sidetrack Mud Program: • Milling/drilling: 8.5 8.9 pg 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: • 2 3/8" solid cemented liner 9100' - 12050' . • The liner cement volume is planned to be 13 is of 15.8 ppg class G. Casing/Liner Information 13-3/8", L-80, 68#, Burst 5020, collapse 2270 psi 9-5/8", NT-80, 47#, Burst 6870, collapse 4750 psi 7", NT-80, 27#, Burst 7240, collapse 5410 psi 2 318" 4.7# L-80 Burst 11200, collapse 11780 ~ Planned Liner 2 3/8" L-80 STL 4.6#, Burst 11200 psi; collapse 11780 psi (hole size 3.0") 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. /f The annular preventer will be tested to 400 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 93 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line: 29,0 ~t • Distance to nearest well within pool: 48 f (TVD) to 15-25A at 10,110'. Logging • MWD directional and Gamma Ray will be run over all of the openhole section. • MCNL will be run cased hole. Hazards • DS 15 is not designated as an HZS pad. • Minor fault crossings not expected to cause lost circulation. Reservoir Pressure Res. press. is estimated to be 3288psi at 8800'ss (7.2 ppg EMW).' Max. surface pressure with gas (0.10 psilft) to surface is 2400 psi. TREE= FMC WELLHEAD = CM! ACTUATOR = AXELSON KB. ELEV = 64.6' BF. ELEV = KOP = 5540' Max Angle = 95 11219' Datum MD = N/A DatumTVD = 8800' SS 41/2" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" ~--I 2926' 13-3/8" CSG, 68#, L-80, ID= 12.415" 3540' TOPOF7" LNR ~--~ 8651' 9-5/8" CSG, 47#, NT-80S, ID = 8.681 " 8862' Minimum ID =1.75" @ 9853' KB LNR TOP PKR SEAL UNIT TBG PUNCH (05/30/02) ~--~ 1 TOP OF WH IPSTOCK aBP(o5/28/02) I-{ 10150' PERFORAl10N SUMMA RY REF LOG: SPERRY MWD GR/DENS/NflJ7 ON 09/27192 ANGLE AT TOP Pff2F: 91 @ 10825' Note: Refer fp Production DB fo r historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 1-11/16" 4 10825 - 11150 O 06/15/02 1-11/16" 4 11300 - 11875 O 06/15/02 1-11!16" 4 11950 - 12120 O 06/15/02 1.56" 6 10600 - 10640 O 12/04!03 1.56" 6 10665 - 10685 O 12/04/03 ~T' LNR, 27#, NT-80s, .0383 bpf, ID = 6.276" 11084' 1!2" LNR, 12.63", L-80, .0152 bpf, D = 3.958" 11728' 15 -31 A SA~ NOTES: 207$' 4-1 /2" CAM00 TRDP-4A-SC SSSV NP, ID= 3.812" 2926' 4-1 /2" X 3-1/2" XO C;AS I IFT MANfA2Fl S ~ ST MD TVD DEV TYPE VLV LATCH FLIRT DATE 1 3188 3188 1 CA-MMG-2 DMY RK 0 04/17/04 2 5497 5493 8 CA-MMG-2 DMY RK 0 04/17/04 3 6970 6872 28 CA-MMG-2 DMY RK 0 4 8377 7984 50 CA-MvtG-2 DMY RK 0 5 8503 8062 55 CA-MvtG-2 DMY RK 0 --' 9031' H 3-1 /2" PARKER SWS NIP, D = 2.813" 9050' 3-112" X 4-112" XO 9053' 7" X 41/2" ~ KER SA BL-3 PKR 9057' 4-1/2"X3-112"XO 9071' 3-1 /2" PARKER S WS NIP, D = 2.813" 9833' fB LNR TOPPKR, ID= 1.75" 9857' 3" BKR DEPLOYMBdTSLV, ID= 2.700" 9863' 2-3/4" X 2-3/8" XO, ID = 1.995" 12140' PBTD 10725' GBP(o5/2s/o2) 10771' TM/ SS PKR 2-3/8" TBG, 4.7#, L-80, .00387 bpf, ID= 1.995" H 12178' DOTE REV BY COMMBVTS DATE REV BY COMMENTS 70/01/92 ORIGINALCOMPLETION 09/1?J03 CJulO/TLP DATUM MD&PERFANGLE/R~ 09/01!93 LAST WORKOVER 11/29/03 BJMcIWTL LNR TOP PKR, TBG IDBPF 06/76/02 JDM/KK CTD SIDETRACK 12/04/03 McLlfLP PERFS 06124/02 JNVKAK GLV GO 04/17/04 JLJ/KA K GLV C/O 08/15ro2 GGKAK MIN ID CORRECTION 06!13!03 CMOIRP KB ELEVATION CORRECTION PRUDHOE BAY UNIT WELL: 15-31 A PfftMIT No: 2021020 API No: 50-029-22285-01 SEC 22, T11 N, R14E, 4597.85' FEL & 2653.89' FNL BP Exploration (Alaska) TREE = FMC: 4-1l2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 13-3/8" CSG, 68#, L-80, ID = 12.415" I TOP OF 7" LNR 9-5/8" CSG, 47#, NT-80S, ID = 8.681" PERFORATION SUMMARY REF LOG: SPERRY MWD GR/DENS/NEUT ON 09/27/92 ANGLE AT TOP PERF: 91 @ 10825' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 10825 - 11150 isolated proposed 1-11/16" 4 11300 - 11875 isolated proposed 1-11/16" 4 11950- 12120 isolated proposed 1.56" 6 10600 - 10640 isolated proposed 1.56" 6 10665 - 10685 isolated proposed PUNCH (0 TOP OF i3-1/2" TBG, 9.2#, L-80, TDS, ID = 2.990" 10766' 2-3/8" TBG, 4.7#, L-80, .00387 bpf, ID = 1.995" 12178' 7" LNR, 27#, NT-80S, NSCC, 0.0383 bpf, ID = 6.276" 11084' I I 4-1/2" LNR-SLTD, 12.63#, L-80, FL4S, 0.0152 bpf, ID = 3.958" 11728' ~ 2-3/8" cmt'ed and 9650' 9775' 9825' 12050' I CIBP -~ Tubing Punch KB LNR TOP PKR, ID = 1.75" 3" BKR DEPLOYMENT SLV, ID = 2. 2-3/4" X 2-3/8" XO, ID = 1.995" PRUDHOE BAY UNfT WELL: 15-31 B PERMfT No: API No: 50-029-22285-02 SEC 22, T11 N, R14E, 4597.85' FEL 8 2653.89' FNL BP Exploration (Alaska) 15-31 B ' Proposed CTD Sidetrack O SAFETY NOTES: 1 4-1/2" CAMCO TRDP-4A-SC SSSV NIP, ID = 3.812" 4-1/2" X 3-1/2" XOl GAS LIFT MANDRELS i 3188 2 5497 3 6970 4 8377 5 8503 3188 5493 6872 7984 8062 1 8 28 50 55 CA-MMG-2 CA-MMG-2 CA-MMG-2 CA-MMG-2 CA-MMG-2 DMY DMY DMY DMY DMY RK 0 04/17/04 RK 0 04/17/04 RK 0 RK 0 RK 0 9031' 3-1/2" PARKER SWS NIP, ID = 2.813" 9050' 3-1/2" X 4-1/2" XO 9053' 7" X 4-1/2" BAKER SABL-3 PKR~ 905T a-v2" x 3-v2° xo~ 9071' 3-1/2" PARKER SWS NIP, ID = 2.813" 9100' Top of /8" L 9100' Top of Cement 9150' Tubing Punch BP r.r«rt rr.twtnr teat TM en Mar Ye44Je Neretc . tt.t. wtwr~ 4e ~ at twtwx oomo u.twn v. ~ ~~ ~e~ii ew~a.~i o _ _ _ _t_tt.w~ o.oo o.oo ».ao REFERENCE INFORMATION CooNinale (N/E) Rakrence.- WeA Centre: 1531, True North Vertical (ND) Reference: System: Mean Sea level Section (VS) References Sbt - 31 (O.OON.O.OOE) Measurao Depm Reference: 45:31 9/6/1992 00:00 64.60 Calculation Methoo: Minimum Curvature ..~. ~ ~ .w .~_.. Po~ :~ ...._.. LEGEND T ,gZimulhs to True North Plan: Plan #5 (1531/Plan#5, 15318) iS31 1l1537) --- 1531 (1S31A7 M Magnetic North: 24.84° CrealeA By: Bil Michaelson Dale: 5!3!2005 - PIaMrS, 15318 __ _ _ _ _ ___ ~t'1 - Ra„A5 ~ Magnetic Field FF'' Stren Ih: 57843nT Co~laGt mrn.matwn. g James Ohlinger Dip Angle: 80.66° olreu: (907) 267-6610 Date: 5/2/2005 cen: (907) 250-7375 Model: bggm2004 6mae: jamesohlinger@inteq.com 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 West(-)/East(+) [100ft/iin] {' i; 'I t_:: ~~_{ 4~~..ii '~ ii ' ;' +~.. i I '.: II j.l l.' ,.~~. ~. ~; ;!.~~ :. i ti-'-: 10 4900 ..I.~ - 0 5400 PM n ~J • • Baker Hughes INTEQ ~~~~~ ~~~~ Baker Hughes INTEQ Planning Report ~,-i ~.~~ ~ ~~~-- j Company: BP Amoco ~ Date: 5/3/2005 Time: 13:45:15 Page: 1 l ~ Field: Prudhoe Bay Co-ordinate(NE) Rcference: ' Wetf: 15-31, True North Site: PB DS 15 Nell: 15-31 ~Vellpathi Plan#5, 15-31B Vertical (TVD) Reterence: 45:31 916/1992 00:00 64.6 Section (VS) Reference: Well (O.OON,O.OOE,111.60Azi) Survey Calculation Method:. Minimum Curvature Db: Oracle ~ Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: PB DS 15 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5958837 .36 ft Latitude: 70 17 35.236 N From: Map Easting: 676296 .98 ft Longitude: 148 34 21.213 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: 15-31 Slot Name: 31 15-31 Well Position: +Nf-S 715.24 ft Northing: 5959578 .38 ft Latitude: 70 17 42.270 N +E/-W 1109.70 ft Easting : 677389 .53 ft Longitude: 148 33 48.870 W Position Uncertainty: 0.00 ft Wellpath: Plan#5, 15-31B Drilled From: 15-31 50029 Tie-on Depth: 9 544.85 ft Current Datum: 45:31 9/6/1992 00:00 H eight 64 .60 ft .Above System Datum: Mean Sea Level Magnetic Data: 512/2005 Declination: 24.84 deg - Field Strength: 57643 nT Mag Dip Angle: 80.86 deg Vertical Section: Depth From (TVD) +N!-S . +E/-W Direction ft ft ft deg : 33ft0 . 0.00 0.00. 111;60 ; Plan; Plan #5 Date Composed: 5/2/2005 CopyLamar's PIanS Version: 4 Principal: Yes Tied-to: From : Definitive Path Targets - _ _ - --- Map Viap <__ Latitude -> <- Longitude -> ~ ~ Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 15-316 Polygon 64.60 992.23 3157.13 5958661.00 680569.00 70 17 32.505 N 148 32 16.864 W -Polygon 1 64.60 -992.23 3157.13 5958661.00 680569.00 70 17 32.505 N 148 32 16.864 W -Polygon 2 64.60 -1624.04 3987.51 5958049.00 681414.00 70 17 26.287 N 148 31 52.675 W -Polygon 3 64.60 -1911.50 4214.80 5957767.00 681648.00 70 17 23.459 N 148 31 46.057 W -Polygon 4 64.60 -1900.66 4518.16 5957785.00 681951.00 70 17 23.564 N 148 31 37.217 W -Polygon 5 64.60 -1362.48 4433.83 5958321.00 681854.00 70 17 28.857 N 148 31 39.665 W -Polygon 6 64.60 -896.53 3764.60 5958771.00 681174.00 70 17 33.443 N 148 31 59.160 W -Polygon 7 64.60 -739.22 3245.14 5958916.00 680651.00 70 17 34.993 N 148 32 14.297 W -Polygon 8 64.60 -540.36 3084.77 5959111.00 680486.00 70 17 36.949 N 148 32 18.968 W -Polygon 9 64.60 -510.11 2862.41 5959136.00 680263.00 70 17 37.248 N 148 32 25.448 W -Polygon 10 64.60 -704.20 2905.85 5958943.00 680311.00 70 17 35.339 N 148 32 24.184 W 15-31B Fault1 64.60 -1670.48 3285.17 5957986.00 680713.00 70 17 25.834 N 148 32 13.142 W -Polygon 1 64.60 -1670.48 3285.17 5957986.00 680713.00 70 17 25.834 N 148 32 13.142 W -Polygon 2 64.60 -715.74 3860.90 5958954.00 681266.00 70 17 35.221 N 148 31 56.351 W 15-316 Fault3 64.60 -2049.79 4648.69 5957639.00 682085.00 70 17 22.096 N 148 31 33.416 W -Polygon 1 64.60 -2049.79 4648.69 5957639.00 682085.00 70 17 22.096 N 148 31 33.416 W -Polygon 2 64.60 -2725.02 8801.18 5957062.00 686252.00 70 17 15.419 N 148 29 32.444 W 15-31 B Fault4 64.60 -1894.47 3832.07 5957775.00 681265.00 70 17 23.628 N 148 31 57.209 W -Polygon 1 64.60 -1894.47 3832.07 5957775.00 681265.00 70 17 23.628 N 148 31 57.209 W -Polygon 2 64.60 -1543.15 3400.22 5958116.00 680825.00 70 17 27.086 N 148 32 9.788 W 15-31 B Fault2 64.60 -1570.98 4578.96 5958116.00 682004.00 70 17 26.806 N 148 31 35.440 W -Polygon 1 64.60 -1570.98 4578.96 5958116.00 682004.00 70 17 26.806 N 148 31 35.440 W -Polygon 2 64.60 -719.57 4574.05 5958967.00 681979.00 70 17 35.179 N 148 31 35.568 W y, , Baker Hughes INTEQ ~~+~~~ `` Baker Hu hes INTE Plannin Re ort - _ --- g Q g P l~-re.c~~ ~ Company: . BP Amoco Date: 5/3/2005 Time: 13:45:15 Page: 2 ~ Field: Prudhoe Bay Co-or dinate(NE) Reference Well: 45-31, True North Site: PBDS 15 Vertical (TVD) Reference: 45 ' 31 9/6/1992 00:00..64.6 Well: 15-31 Secfiou (VS) Reference: Well (O.OON,O.OOE,111.60Azi) ~~Vel-path:_ Plan#5, 15_-31B__ __ _ _ _ _ _ _ __ Survey Calculation Method: _Minimum Curvature __ _Db_ Oracle __ ~ Targets ~ --- ------ -- ----- ----- ------ Map biap <~ Latitude --> -I <- Lon~itudc -> i Name Description TVD +N/-S +E/-W Northing Fasting Deg :Vlin Sec Deg Min Sec ~ ~ Dip: Dir. ft ft ft ft ft 15-31 B Faults 64.60 -487.31 2574.85 5959152.00 679975.00 70 17 37.473 N 148 32 33.828 W -Polygon 1 64.60 -487.31 2574.85 5959152.00 679975.00 70 17 37.473 N 148 32 33.828 W -Polygon 2 64.60 -107.85 3366.08 5959550.00 680757.00 70 17 41.202 N 148 32 10.764 W 15-31 B Target4 8795.60 -1731.20 4374.11 5957951.00 681803.00 70 17 25.231 N 148 31 41.412 W 15-316 Target3 8799.60 -1620.66 4225.67 5958058.00 681652.00 70 17 26.319 N 148 31 45.735 W 15-316 Target2 8832.60 -1208.46 3672.21 5958457.00 681089.00 70 17 30.376 N 148 32 1.857 W 15-31 B Targets 8844.60 -814.87 3102.30 5958837.00 680510.00 70 17 34.249 N 148 32 18.460 W Annotation i~ID TVD I ft ft 9544.85 8587.24 TIP 9650.00 8623.82 KOP 9670.00 8630.96 End of 9°/100' DLS .. 9700.00 8643.38 4 9850:00 $703.90 5 10000.00 8752.47 6 10100.00 8781.92 7 10250.00 8824.82 8 - 10400.00 8845.65 End of 18°/100' DLS 10600.00 8843.10 10 11000.00 8835.55 11 11150.00 8833.45 12 11300.00 8829.42 13 11550.00 8816.57 14 11825.00 8800.81 15 12050.00 8796.12 TD Plan Section Information --- MD Iucl Aaim TVD kN/-S +Ef-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft degl100ft deg/100 ft deg 9544.85 69.29 98.74 8587.24 -427.30 2392.63 0.00 0.00 0.00 0.00 9636.19 69.90 99.31 8619.08 -440.73 2477.18 0.89 0.67 0.62 41.31 9650.00 69.99 99.28 8623.82 -442.83 2489.98 0.68 0.65 -0.22 342.61 9670.00 68.19 99.28 8630.96 -445.84 2508.42 9.00 -9.00 0.00 180.00 9700.00 62.88 100.33 8643.38 -450.49 2535.31 18.00 -17.72 3.51 170.00 9850.00 70.36 128.67 8703.90 -507.66 2658.42 18.00 4.99 18.89 80.00 10000.00 72.55 100.26 8752.47 -565.62 2786.36 18.00 1.48 -18.94 270.00 10100.00 73.45 119.07 8781.92 -597.66 2875.94 18.00 0.88 18.81 90.00 10250.00 73.95 147.21 8824.82 -694.99 2979.73 18.00 0.33 18.77 93.00 10400.00 90.22 125.38 8845.65 -800.98 3081.81 18.00 10.85 -14.55 305.00 10600.00 91.22 101.40 8843.10 -879.80 3264.01 12.00 0.50 -11.99 272.50 11000.00 90.82 149.41 8835.55 -1104.78 3580.53 12.00 -0.10 12.00 90.00 11150.00 90.78 131.41 8833.45 - 1219.88 3675.73 12.00 -0.03 -12.00 270.00 11300.00 92.28 113.46 8829.42 -1299.98 3801.77 12.00 1.00 -11.96 275.00 11550.00 93.48 143.48 8816.57 -1453.49 3995.03 12.00 0.48 12.01 87.00 11825.00 92.91 110.43 8800.81 -1616.24 4211.42 12.00 -0.20 -12.02 270.00 12050.00 89.43 137.21 8796.12 - 1740.32 4396.56 12.00 -1.55 11.90 97.00 s • Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~~~ ~~~~~ ~~ r~~c~ _ ___._~. i Company: BP Amoco ~ Date: 513/2005 Tiine: 13:45:15 ~ Page: 3 Field: Prudhoe Bay Co-ordinate(I`E) Reference WeIP 15-31, True North Site: PB DS 15 Vertical{TVD)Refereuce: 45: 31 9!611992 00:00 64:6 Well: 15-31 Section (VS) References Well (O.OON,O.OOE,111:60Azi)' ~ Wellpath: Play#5, 15-316 Survey Calculation Viethod: MihimumCurvature Db: -0racle a„ ~. a. N1D Ind Azim SSTVD N/S El~'V MapN D1apE DLS VS TFO .Tool ft deg deg ft ft ft ft ft deg(100ft ft deg 9544.85 69.29 98.74 8522.64 -427. 30 2392.63 5959207.69 679791,43 0.00 2381.95 0.00 MWD 9550.00 69.32 98.77 8524.46 -428 .04 2397.39 5959207.06 679796.20 0.89 2386.65 41.31 MWD 9575.00 69.49 98.93 8533.25 -431. 64 2420.52 5959204.01 679819.41 0.89 2409.47 41.30 MWD 9600.00 69.66 99.08 8541.98 -435 .31 2443.65 5959200.89 679842.62 0.89 2432.34 41.24 MWD 9625.00 69.83 99.24 8550.63 -439. 04 2466.81 5959197.70 679865.86 0.89 2455.24 41.19 MWD 9636.19 69.90 99.31 8554.48 -440. 73 2477.18 5959196.26 679876.26 0.89 2465.51 41.14 MWD 9650.00 69.99 99.28 8559.22 -442 .83 2489.98 5959194.46 679889.11 0.68 2478.18 342.61 MWD 9670.00 68.19 99.28 8566.36 -445. 84 2508.42 5959191.59 679907.61 9.00 2496.43 180.00 MWD 9675.00 67.30 99.45 8568.25 -446 .59 2512.98 5959191.24 679912.19 18.00 2500.96 170.00 MWD 9700.00 62.88 100.33 8578.78 -450 .49 2535.31 5959187.88 679934.61 18.00 2523.15 169.94 MWD 9725.00 63.74 105.27 8590.01 -455 .44 2557.09 5959183.44 679956.49 18.00 2545.22 80.00 MWD 9750.00 64.78 110.14 8600.88 -462. 29 2578.53 5959177.10 679978.09 18.00 2567.67 77.78 MWD 9775.00 65.97 114.91 8611.30 -470 .99 2599.51 5959168.89 679999.27 18.00 2590.39 75.67 MWD 9800.00 67.30 119.59 8621.22 -481. 50 2619.90 5959158.87 680019.90 18.00 2613.22 73.68 MWD 9825.00 68.77 124.18 8630.57 -493 .75 2639.58 5959147.09 680039.86 18.00 2636.02 71.82 MWO 9850.00 70.36 128.67 8639.30 -507 .66 2658.42 5959133.63 680059.02 18,00 -2658.66 - 70.10 MWD 9875.00' 70.43 123.90 8647.70 -521 .59 2677.40 5959120.15 680078.32 18.00 2681:43 `270:00- MWD 9900.00 70.6E 119.13 8656.04 -533 .90 2697.48 5959108:32 ' 680098.69 18.00 2704;64 271.60` MWD 9925.00 70:93 - 114.37 8664.27 -544 .52 2718.56 5959098.20 680120.01 18AO - 2728:14 273.19' 'MWD 9950.00 71.36 109.64 8672.36 -553. 38 2740.48 5959089:86 680142.14 18.00 2751.79 274.76 MWD 9975.00'. 71.91 104.93 8680.24 -560 .43 2763.13 5959083.35 680164.94 18.00 `2'775.44 276.29 MWD 10000.00 72.55 100.26 8687.87 -565 .62 2786.36 5959078.71: 680188.29 18.00 2798:95 277.78 MWD 10025.00 72:63 104.97 8695.35 -570 .83 2809.63 5959074.05 680211.67 18.00 '2822.51 90.00 MWD 10050.00 72.80. 109.68 8702.78 -577 .94 2832.41 5959067.48 680234':61 18:00 2846.30 88.59 MWD 10075.00' 73.07 114.38 8710.12 -586 .90 2854.56 5959059.05 680256.96 18.00 2870.19 87.19 MWD 10100.00 73.45 119.07 8717.32 -597 .66 2875.94 5959048.79 680278.59 18.00 2894.03 85.81 MWD 10125.00 73.27 123.76 8724.48 -610 .14 2896.37 5959036.80 680299.31 18.00 2917.63 93.00 MWD 10147.58 73.20 128.00 8731.00 -622 .81 2913.89 5959024.54 680317.12 18.00 2938.58 91.66 15-318 10150.00 73.19 128.46 8731.70 -624 .24 2915.70 5959023.16 680318.97 18.00 2940.79 90.43 MWD 10161.42 73.19 130.60 8735.00 -631 .20 2924.13 5959016.40 680327.56 18.00 2951.19 90.30 15-31 B 10175.00 73.22 133.16 8738.92 -639 .88 2933.81 5959007.95 680337.44 18.00 2963.39 89.68 M W D 10200.00 73.36 137.65 8746.11 -656 .96 2950.59 5958991.28 680354.62 18.00 2985.27 88.94 MWD 10225.00 73.60 142.54 8753.23 -675 .36 2965.93 5958973.24 680370.38 18.00 3006.30 87.59 MWD 10250.00 73.95 147.21 8760.22 -694 .99 2979.73 5958953.95 680384.65 18.00 3026.36 86.26 MWD 10275.00 76.56 143.43 8766.58 -714 .86 2993.49 5958934.40 680398.87 18.00 3046.47 305.00 MWD 10281.26 77.22 142.49 8768.00 -719 .73 2997.16 5958929.63 680402.65 18.00 3051.67 305.96 15-31 B 10300.00 79.23 139.72 8771.82 -734 .01 3008.68 5958915.63 680414.50 18.00 3067.64 306.18 MWD 10325.00 81.94 136.08 8775.92 -752 .30 3025.21 5958897.73 680431.46 18.00 3089.74 306.74 MWD 10350.00 84.68 132.49 8778.83 -769 .63 3042.99 5958880.$3 680449.64 18.00 3112.65 307.34 MWD 10375.00 87.45 128.93 8780.54 -785 .89 3061.89 5958865.02 680468.92 18.00 3136.21 307.76 MWD 10400.00 90.22 125.38 8781.05 -800 .98 3081.81 5958850.40 680489.19 18.00 3160.28 308.00 MWD 10425.00 90.35 122.38 8780.93 -814 .92 3102.56 5958836.96 680510.26 12.00 3184.71 272.50 MWD 10450.00 90.48 119.39 8780.75 -827 .75 3124.01 5958824.64 680532.01 12.00 3209.37 272.49 MWD 10475.00 90.61 116.39 8780.51 -839 .44 3146.10 5958813.47 680554.37 12.00 3234.22 272.46 MWD 10500.00 90.74 113.39 8780.21 -849 .96 3168.78 5958803.49 680577.28 12.00 3259.17 272.43 MWD 10525.00 90.86 110.39 8779.86 -859 .28 3191.97 5958794.72 680600.69 12.00 3284.17 272.40 MWD 10550.00 90.98 107.40 8779.46 -867 .37 3215.61 5958787.19 680624.52 12.00 3309.13 272.36 MWD 10575.00 91.10 104.40 8779.01 -874 .22 3239.65 5958780.91 680648.71 12.00 3334.00 272.31 MWD 10600.00 91.22 101.40 8778.50 -879 .80 3264.01 5958775.91 680673.19 12.00 3358.71 272.25 MWD 10625.00 91.22 104.40 8777.97 -685 .38 3288.37 5958770.91 680697.67 12.00 3383.41 90.00 MWD 10650.00 91.21 107.40 8777.44 -892 .23 3312.41 5958764.63 680721.86 12.00 3408.28 90.06 MWD 10675.00 Af~7nn nA 91.20 nA AA 110.40 AAA] w0 8776.91 O~7n_ nn -900 nnn .32 Cc 3336.05 O~fcn nA 5958757.09 LncO7w0 nn 680745.69 COn'7Ln AA 12.00 AA An 3433.25 ~]ALO 1A 90.13 AA An MWD \AIw/!1 • Baker Hughes INTEQ #~~ ~~,~~~ Baker Hughes INTEQ Planning Report ~ ;~ ~. ~~ - - ---- r-- - Company: ---- BP Amoco Date: 5/3/2005 .Time: 13:45:15 Pagec 4 ~ I Field: Prudhoe Bay Co-ordinate(NE)Reference. -Weft, 15-31, True North Site: PB DS 15 Vertical (TVD) Reference: 45:31 9/6/1992.00:0084.6 Well: 15-31 Section (VS) Reference: Welt (O.OON,O.OOE,111.60Azi) Weilpath: L---- Plan#F5, 15-316 -------------- Survey Calculation Method: -- ----------------- Minimum Curvature Db: Oracle ---------------------J Survey r- --------------- ------------------------------------------- ~ ~1D Inc) lzim SS TVD NlS EIW blapl~i MapE DLS VS TFO .Tool ~ ft deg deg ft ft ft ft ft deg/100ft ft deg ~~ 10725.00 91.18 116.40 8775.87 -920.17 3381.91 5958738.34 680792.00 12.00 3483.19 90.25 MWD 10750.00 91.16 119.40 8775.36 -931.86 3404.00 5958727.17 680814.35 12.00 3508.03 90.32 MWD 10775.00 91.14 122.40 8774.86 -944.70 3425.44 5958714.84 680836.09 12.00 3532.69 90.38 MWD 10800.00 91.11 125.41 8774.37 -958.64 3446.18 5958701.39 680857.16 12.00 3557.11 90.44 MWD 10825.00 91.09 126.41 8773.89 -973.65 3466.17 5958686.86 680877.49 12.00 3581.21 90.50 MWD 10850.00 91.06 131.41 8773.42 -989.68 3485.34 5958671.29 680897.03 12.00 3604.94 90.55 MWD 10875.00 91.02 134.41 8772.97 -1006.70 3503.65 5958654.71 680915.73 12.00 3628.23 90.61 MWD 10900.00 90.99 137.41 8772.53 -1024.65 3521.04 5958637.18 680933.54 12.00 3651.00 90.66 MWD 10925.00 90.95 140.41 8772.11 -1043.49 3537.46 5958618.73 680950.41 12.00 3673.21 90.72 MWD 10950.00 90.91 143.41 8771.71 -1063.16 3552.88 5958599.43 680966.29 12.00 3694.79 90.77 MWD 10975.00 90.86 146.41 8771.32 -1083.61 3567.25 5958579.33 680981.14 12.00 3715.67 90.82 MWD 11000.00 90.82 149.41 8770.95 -1104.78 3580.53 5958558.47 680994.91 12.00 3735.82 90.86 MWD 11025.00 90.81 146.41 8770.60 -1125.96 3593.81 5958537.62 681008.69 12.00 3755.96 270.00 MWD 11050.00 90.81 143.41 8770.24 -1146.41 3608.18 5958517.52 681023.53 12.00 3776.84 269.96 MWD 11075.00 90.81 140.41 8769.89 -1166.08 3623.60 5958498.22 681039.41 12.00 3798.42 269.91 MWD 11:100.00 90.80 137.41 8769.54 -1184.91 3640.03 5958479.77 681056.28 12.00 3820.63 269.87 MWD 11125.00 90.79 134.41 8769.19 -1202.87 3657.42 5958462:24 681074.09 12.00 3843:41 ' 269.83 MWD ` 11150.00 90.78 131.41 8768.85 -1219.88 3675.73 5958445,66 681092.79 12.00 3866'.70 269.79 ` MWD 11175.00 91.04 128.42 8768.46. -1235.92 3694.90 5958430.08 681.112:34 12.00 3890.42 "' -275.00' MWD 11200.00 91.29 125.43 8767.95 -1250.93 3714.88 5958415.55 681132.67 12.00 3914:53 '274.95 MWD 11225.00 91:55 122.44 8767.33 -1264.88 3735.62 5958402.09 681153.72 12.00 " 3938.94 '? 274.89 MWD 11250.00 91.80. 119.45 8766.60 -1277.73 3757.05 5958389.75 681175.45 12.00 3963,59 274.82 MWD 11275.00 92.04 116.45 8765.76 - -1289.44 3779.12 5958378.57 681197.79 12.00 3988.42 274.73 MWD 11300.00 92.28 113.46 8764.82 -1299.98 3801.77 5958368.57. 681220.67 12.00 4013.36 274.63 MWD 11325.00 92.44 116.46 8763.79 -1310.52 3824.41 5958358.57 681243.56 12.00 4038.29 87.00 MWD 11350.00 92.58 119.46 8762.70 -1322.22 3846.47 5958347.38 681265.89 12.00 4063.11 87.12 MWD 11375.00 92.72 122.46 8761.54 -1335.07 3867.88 5958335.05 681287.59 12.00 4087.75 87.25 MWD 11400.00 92.85 125.46 8760.32 -1349.02 3888.59 5956321.59 681308.62 12.00 4112.14 87.39 MWD 11425.00 92.98 128.46 8759.05 -1364.03 3908.54 5958307.06 681328.92 12.00 4136.21 87.54 MWD 11450.00 93.10 131.46 8757.73 -1380.06 3927.67 5958291.48 681348.43 12.00 4159.90 87.69 MWD 11475.00 93.20 134.47 8756.35 -1397.07 3945.93 5958274.91 681367.09 12.00 4183.14 87.85 MWD 11500.00 93.30 137.47 8754.93 -1415.01 3963.28 5958257.38 681384.85 12.00 4205.88 88.02 MWD 11525.00 93.39 140.47 8753.47 -1433.84 3979.66 5958238.95 681401.67 12.00 4228.04 88.19 MWD 11550.00 93.48 143.48 8751.97 -1453.49 3995.03 5958219.66 681417.50 12.00 4249.56 88.36 MWD 11575.00 93.47 140.47 8750.46 -1473.15 4010.40 5958200.38 681433.33 12.00 4271.09 270.00 MWD 11600.00 93.46 137.47 8748.95 -1491.97 4026.78 5958181.95 681450.15 12.00 4293.25 269.82 MWD 11625.00 93.43 134.46 8747.44 -1509.91 4044.13 5958164.43 681467.91 12.00 4315.98 269.64 MWD 11650.00 93.40 131.46 8745.95 -1526.91 4062.39 5958147.86 681486.57 12.00 4339.21 269.46 MWD 11675.00 93.36 128.45 8744.48 -1542.94 4081.52 5958132.29 681506.07 12.00 4362.90 269.28 MWD 11700.00 93.31 125.45 8743.03 -1557.94 4101.46 5958117.77 681526.36 12.00 4386.96 269.10 MWD 11725.00 93.24 122.44 8741.60 -1571.87 4122.17 5958104.33 681547.38 12.00 4411,34 268.92 MWD 11750.00 93.17 119.44 8740.20 -1584.70 4143.57 5958092.01 681569.08 12.00 i 4435.97 268.75 MWD 11775.00 93.10 116.43 8738.83 -1596.40 4165.62 5958080.84 681591.40 12.00 4460.78 268.59 MWD 11800.00 93.01 113.43 8737.50 -1606.92 4188.26 5958070.85 681614.28 12.00 4485.70 268.42 MWD 11825.00 92.91 110.43 8736.21 -1616.24 4211.42 5958062.08 681637.65 12.00 4510.66 268.26 MWD 11850.00 92.54 113.41 8735.02 -1625.56 4234.58 5958053.31 681661.02 12.00 4535.63 97.00 MWD 11875.00 92.17 116.39 8733.99 -1636.08 4257.24 5958043.33 681683.92 12.00 4560.56 97.14 MWD 11900.00 91.79 119.37 8733.13 -1647.76 4279.32 5958032.17 681706.27 12.00 4585.39 97.26 MWD 11925.00 91.40 122.34 8732.43 -1660.57 4300.77 5958019.87 681728.02 12.00 4610.06 97.37 MWD 11950.00 91.01 125.32 8731.91 -1674.49 4321.53 5958006.45 681749.10 12.00 4634.48 97.45 MWD 11975.00 90.62 128.29 8731.55 -1689.46 4341.54 5957991.96 681769.46 12.00 4658.60 97.51 MWD 12000.00 90.22 131.26 8731.37 -1705.45 4360.75 5957976.42 681789.04 12.00 4682.35 97,55 MWD ~,_ Baker Hughes INTEQ ~~~~; Baker Hughes INTEQ Planning Report ~,~ ~ ~..~~ ~ ---- ----- - - - I Companyi BP Amoco I Field:. Prudhoe Bay ~ Site: PB DS 15 We1L• 15-31 i Wellpath_ Plan#5, 15-31B 5urvev Date: 5!3/2005 Time: 13:45:15 Page: 5 Co-ordinate(NE) Reference: Well: 15-31, True North Vertical (TVD) Keferencei 45:31 9/611992 00:00 64.6 Section (VS) Reference: Well (O:OON,000E;111.60Azi) Surrey Calculation Method: Minimum Curvature Db: Oracle MD [ncl Azim SS TVD h!S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft degl100ft ft deg 12025.00 89.82 134.24 i 8731.36 -1722.42 4379.11 5957959.89 681807.79 12.00 4705.66 ' 97.58 MWD 12050.00 ~ 89.43 137.21 8731.52 -1740.32 4396.56 5957942.41 681825.66 12.00 4728.47 97.58 MWD Nordic 1 slimhole i ~_ of bag of pipes cross Imiddle of pipe/slips . - . - BAG Dowell 7 1/16" 5000psi Blind/Shears TOTs ~ 2" combi ram/slips ~ 1/16" 5000psi Mud Cross I I Mud Cross 7 1 /16" 5000psi 2 3/8" ram .. ~ TOTs 2" combi ram/slips ~ 1/16" 5000psi Swab Vale Flow Tee 204 ss-sr, z52 TERRIE l RUBBLE BP EXPLORATION. A5 {NC "Mastercard Check ~~ MB -~ „ DATE PO 60X'196612 C~ ANCHORAGE, AK 99519-6612 $ 1~ PAY 70 THE t~,k.~ARS ORDER OF First National Bank Alaska Anchorage, AK 99501 MENrO._a-`~ ~„ i 5 ~6~~~ o X04 _ ~: L 25 200060:99 L4~n~6 2 27 • • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /~,~r,/ I ri ^ ~~~ PTD# ~D,~~r55~" is 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(f), all (per records, data and logs acquired for the pilot hole must be clearly differentiated in both name (Warne on permit plus PH) and API number (50 - 70/SO) 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 produceiiniect is contingent upon issuance of a conservation order approving a spacing exception. (Comaany Name1 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: 04/01/05 C\jody\trans m ittai_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL-640150 PTD~ Administration 10 11 Appr Date 12 RPC 5!31/2005 13 14 ~15 7 ____ __Well Name: PRUDHOE BAY UNIT 15-31B Program DEV Well bore seg Initial GlasslType = DEV 11-OIL _GeoArea 890 _ _ Unit 11650 On/Off Shore On _, Annular Disposal i I ermiteeattached_ -_- --__- ___-_ -_--- ___ Yes_,_-_.__.__- _ Lease number appropriate______ _____________ ____________ __- - Yes_____-__._ Uniquewell_nameandnumber___-__________________________.___-- Yes_______-__--_-____.__-_,--_ Well-located in a_defined_pool_ - _ _ _ _ _ _ , _ _ _ - _ _ . , YeS _ _ - _ _ _ _ _ Well located proper distance from dri_Iling unit_boundary_ Yes _ - _ Well locatedproperdistancefromotherwells__________ ___________________ Yes-__,____,-_ Sufficient acreage available in-drilling unit_ - _ - _ Yes _ . - Ifdeyiated,is_wellboreplatincluded________________ ____ Yes--_.-_____-__-__-___ -__._________._ Operator only affected party__________________ Yes_ --___ Operatorbas-appropriate_bondinforce_________________________-__.__- Yes--_,_-__--__-___-_ Permit-can be issued withoutco_nseMafionorder__-_-____.__-.___--___,_-_ Yes____ __________ _ ___--._-_,_-__-_- _-_--_--__-.--___-.----__ -_ - Permitcan be issued without ad_minist[ativ_e-approval _ - Yes Can permit be approved before 15-day wait Yes Well located within area and_strata authorized by Injection Order# (put1O# in_comments)-(For_ NA_ - Allwells-within 1/4_milearea of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ - - _ , - _ _ - - _ - . _ _ - - _ -------------------------------------------------------- Pre-produced injector: duration of pre production less than 3 months_(FOrseNice well only) - NA_ _ - - .. - - - - , - ACMP,Finding of Consistency,h_as been issued-for this project- NA- . - Engineering '18 _C_anductorstring.provided__,__._..__________________________ __._NA____,_-__ __, 19 Surface-casing protects aII known USDWs - - - - - - ~ - - - _ 20 CMT_vol-adeguake_tocitcul_aie,onconductor&5urf_csg_________--- __ N_A________ __________ ___ ________.- _-.-_--_---- -____ 21 CMT-vol_ adequate_to tie-in long string to surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _N_A- _ _ _ _ _ 22 CMT. will coyer all known pCoductive horizons_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ - _ - . _ _ _ . _ Yes _ 23 Casing designsadequaleforC,T6&_p_ermafrost__________________ __ .__-_Yes___--____- i24 Adequate tankage_or reseNe pit - _ - - _ _ _ _ _ _ - Yes - _ _ - _ _ - CTl)tl. - _ - _ 25 If_a_re-drill, has_a 10-403 for abandonment been approved . - Yes - . . - _' 26 Adequatewellboreseparationproposed_._________________________ _____Yes-__-__,-___.__-_____ -_ - ~27 If_diverterrequi_red, does it meet regulations___________ ______________ - _ -_______-_ ------ ---- ------------------------ ____ NA_ __--__$idetrack.__-__-____-____.____-._ Appr Date 28 Drilling fluid_program Schematic & equip IiStadequate_ Yes - - . _ - Max MW_8.9 ppg, . WGA 611/2005 29 BOPEs,datheymeet_regulation-_-- „_,_--_ ___-, .-__-Yes_______________________ 30 _B_OPE_press rating appropriate; test to-(put prig m comments)_ - Yes . - - Test to 3500 psi. _MSP 2400 psi._ _ . X31 Choke_manifold comp_Iies w/APL RP-53 (May 84) _ Yes I32 Work will occur without operation shutdown___--_-__-_____-__.__-_ _ _ - -,__Yes-------------__-___-__.__ X33 Ispresence-ofH2Sgas_probable___--__-___-___ -__-_-______ _,___ N_o____- _NotanH2SPad______________ _- 34 Mechanical_coptlition of wells within AQR verified GFor s_eruice well only) _ NA _ _ _ - _ , -_ Geology 5 --- - - Permitcan be issued wlo hydrogen_sulfide measures - - - ~ , No_ - _ _ . 36 Data_presented on-potential overpressure zones_ - .. - . NA Appr Date 37 Seismic analysis of shallpw gas zones_ - - - _ - .. _ _ - - NA, RPC 5131/2005 38 Seabed condition survey (ifoff-Shore) - NA_ _ j39 -Contact namelphone_for weekly progreSS_reports [exploratory only]_ - NA_ - . _ _ Geologic Engineering Pub' Date: Date Date Commissioner: Commissioner: Co ss r DTs ~~~~~ ~~~~,~.6 ~~ / ~'~ • Well Hisfory File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special-effort has been made to chronologically . organize this category of information. '~ • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Nov 21 15:46:53 2005 Reel Header Service name ........ .....LISTPE Date ................ .....05/11/21 Origin .............. .....STS Reel Name ........... .....UNKNOWN Continuation Number. .....01 Previous Reel Name.. .....UNKNOWN Comments ............ .....STS LIS Writing Library Tape Header Service name ........ .....LISTPE Date ................ .....05/11/21 Origin .............. .....STS Tape Name ........... .....UNKNOWN Continuation Number. .....01 Previous Tape Name.. .....UNKNOWN Comments ............ .....STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 5 JOB NUMBER: MW0003802816 LOGGING ENGINEER: B. JAHN OPERATOR WITNESS: B. HOLT / B. SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD s 13417 aD5_o~ Scientific Technical Services Scientific Technical Services 15-31B 500292228502 BP Exploration (Alaska) Inc. Sperry Drilling Services 21-NOV-OS MWD RUN 7 MWD RUN 9 MW0003802816 MW0003802816 B. JAHN S. LATZ B. HOLT / B. B. HOLT / T. 22 11N 14E 1937 1438 64.60 RECEIVED aEC 0 7 2005 OPEN HOLE CASING DRILLERS '~ ~~$gIO~) ~ BIT SIZE (IN) SIZE (IN) DEPTH (FT) R~iW 1ST STRING 3.000 4.500 9667.0 ~~ 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS). 3. 15-31B WAS DRILLED FROM A WHIPSTOCK POSITIONED IN THE 15-31 WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 9662'MD/8563'TVDSS AND THE BOTTOM WAS AT 9667'MD/8565'TVDSS. 4. MWD RUNS 1-4 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. RUN 1 WAS A TIE-IN RUN - THESE SGRD DATA WERE MERGED WITH RUN 5 DATA. MWD RUNS 2-4 WERE MILLING RUNS - NO DATA ARE PRESENTED. 5. MWD RUNS 5-9 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. NO DATA WERE ACQUIRED ON RUNS 6 & 8 DUE TO TOOL FAILURES. SGRD DATA ARE BOREHOLE COMPENSATED FOR HOLE DIAMETER, KCL CONCENTRATION, AND MUD WEIGHT. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY RUN ON 7/16/2005 IN 15-31B. THESE LOG DATA WERE PROVIDED TO SDS BY D. DORTCH (SAIC/BP) ON 10/12/05, AS AUTHORIZED BY STEVE JONES, BP GEOLOGIST. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1-9 REPRESENT WELL 15-31B WITH API#: 50-029-22285-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12210'MD/8737'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED NATURAL GAMMA RAY. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/21 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9290.5 12187.5 ROP 9672.0 12211.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 9290.5 9290.0 9305.5 9305.0 9315.0 9314.5 9321.5 9320.0 9386.0 9384.0 9387.5 9385.5 9407.5 9406.0 9411.0 9409.5 9414.5 9413.5 9669.5 9668.0 9683.5 9682.0 • lf1 I.f) In N N O O Lfl O O Lfl 111 O Lfl O O Ifl O Vl O lfl In N N Ul In N ul lIl l71 N L(1 O O O O Ifl lfl U1 O lf1 O Lfl Ifl Ln O N O lf1 O O Lfl O Lf1 O O O O I.f) O lfl O O lf1 O l1) O O O In N O O N N Ul • N O7 M r M r-I 41 O Ol O~ M 01 lf1 rl l0 M N r-I W Ln r l~ N 61 ~-1 l0 ri N N ~D W N Vl T O r 41 rl O M r ri cr r M M ~D M M O rl Ol N O d~ N d~ M Ifl N M ri ~ I.(l ri r O~ N lf1 r M O OD 01 ~ 01 Ol O O rl N d~ In N 10 r r m Ol T O O rl ri N M T 10 r m o7 Ol r-1 N N N cM d~ r 01 01 01 O N N N M M M r of O ri N M d~ d' If1 r r N CO Ol 01 0l 0 r-I r1 lf1 lO ~D r r a0 Ol 0l 0 ri ri N M l0 l0 r r r r r r r r r r r r r m m m 00 00 N 00 W OJ N OJ W 01 01 Ol 01 01 01 01 Ol Ol Ol 0 0 0 0 0 0 0 0 0 rl rl rl rl rl rl rl rl rl rl ri ri rl ~-I N N N N N N N N N N N M M M M M 01 Ol Ol Ol Ol 01 41 01 ~ 01 Ol Ol Ol Ol 01 Ol Ol Ol Ol Ol Ol 01 Ol 01 Ol 01 01 Ol Ol 01 01 Ol 01 01 ~ Ol Ol 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O O O 0 0 0 0 0 0 0 0 O O O O O ri r~ rl rl rl r1 rl ri rl ~-i rl rl rl ri ~ rl rl ri r~ ri r-I rl ri rl ~-I rl rl rl ri rl r-I ri rl rl ri rl ri rl ri Ill O L!1 lfl N N O O N N N O O N N N N N O U) N O N l() ll) N N N O N L(1 lfl 111 O N Lfl O O N O Ul Ill N O N O N O ul O O O Lfl O Lfl N O O Lfl N O O O Lfl In O N N O O O O O O O N M O If1 ~ lfl M O M ~ r ~ O lD ~ r ~ r M O W 01 Ol d~ ri M 01 M In ul W O In r r N Ol N <T r-I If1 41 N r r-I l0 lfl 10 N Lf1 M d' N Ill d~ ~O rl V' Ill lD 01 M M M O d~ ri d~ 01 rl Ifl M Ol In M r O Ol O O O rl N l17 N L[l ~O r m m 01 Ol O O rl N N M d' ~D [O o~ CO Ol ri N N M d~ d~ r Ol Ol O O N N N M M d~ r c0 O rl N M ~N L!) In r r w CO Ol 01 Ol O W N l0 l0 r r r 01 T O O rl N M I l0 r r r r r r r r r r r r r r m m o7 a0 00 W N N N W a0 N Ol 01 01 Ol Ol Ol Ol 01 Ol 0 0 0 0 0 0 0 0 0 0 r-I rl i-I rl ri ri rl ri i-I rl rl ri rl r1 N N N N N N N N N N M M M M M M Ol Ol Ol Ol 01 Ol 01 01 Ol Ol Ol 01 Ol Ol 01 01 01 Ol 01 Ol ~ Ol 01 Ol Ol Ol Ol O~ Ol 01 Ol Ol O~ O~ ~ Ol 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O O O O O O O O .-~ ri ri ri rl rl ri rl ri rl ~-1 ri ri rl rl ri ri ri ri ri ri ri rl rl rl ri ri rl rl ri rl ri rl ri rl ri rl ri ri ri r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 J ~7 ~] J J ~] J ~] O~ 0~ 01 Ol O~ 01 U1 (I1 U'1 U1 lft Ul ~P ~P W W W W N N N N N N N N N r r r r r r r r r O O O O O O O 10 ~O ~O 10 J Ol Ol 01 01 01 (n In Ul Ul ~P iP ~P iP ~P ~P ~A iP iP W W N J O~ ~P r r O O ~O 10 iA iP W W ~O OD J Ul ~P W 10 J CO Vl W O l0 O] 07 ~] Ul W N N N ~O N J O~ Vl Vi W N O 1D N N Ui iA W r N iA W O O l0 W ~P W N W 0~ N O l0 N J 01 Ol ~P iP N r iP ~P 01 r iP W OJ W J N iP N OD ~P iP O r W r N W W U'1 01 J r N O~ rP OD W r W l0 OD O~ iP 01 O N W J O 01 r Ul 10 1D r O N r N ~] 01 Ul r ~] l0 N W N O~ OD Ul O 01 O r J iP r l0 iA O W O~ iP O (fl 0 0 0 0 0 0 0 Ul Vl Ul O Ul (Il O Ul O Ul O Vt Ul Ul Vl V1 O O N O Ul O O O Ul Ul Vl O Ul Vl O lfl O Ul O Ul Vl O lfl llt O Ul O Vl 0 0 0 0 Ul Vl O 111 Vl Vl O O O Ul Vl O Ul Ul Vl O lfl 0 0 r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 J J J J J J J 01 Ol Ol Ol O~ O~ Ol N U1 U1 U1 U1 U1 ~P .P W W W W N N N N N N N N N r r r r r r r r r O O O O O O O 1p l0 ~O N J 01 01 Ol Ol O~ U1 lJl Ul Ul ~P ~P ~P iP ~P ~P iA iP iP W W W ~] 01 ~P r r O ~D ~O 1D iP ~P W N OJ OD Ol Ul ~P W 10 ~] Co Ul W O ~ 10 OJ J U'1 W N N N 10 J J O~ Ul ~P W N O ~O W N lP 1P W N W iP W ~D O 1D CO ~P N N 00 01 r O l0 00 ~] 0~ 01 ~P iP r O W W Ol r W W 01 r (n N N O J N r m l0 O N O r r O~ N 01 O W O~ J N J N ~P (I1 J U'I W Ul N O r O~ N ~P N O~ ~O O~ r r ~P W O 01 N O N W N N O J W Ol 01 ~O J N O J W O J r lfl OD ~O OD O Ul Ul O O Ul O O Vl O VI Ul Vl Ul Ui N Ul O Ul Ul Ut O N Ul O Ul Ul Ul O O O O Ul O O Ul Ul Ul O O Ul Ul O O Ul Ul Ul (fl O O O Ul (Jl (Jl Ul Ul O Ul O O O O Ul Ul O O lJl O O O O (l1 O (fl Ul O • • 11817 .0 11814.5 11826 .5 11826.0 11832 .0 11831.5 11842. 5 11841.0 11846. 0 11845.5 11853. 0 11850.0 11858. 5 11854.5 11877 .5 11872.5 11895 .5 11890.5 11897 .0 11893.0 11903 .5 11898.5 11914 .5 11912.5 11943. 0 11941.0 11947. 0 11946.5 11949. 0 11949.5 11970. 0 11966.5 11979. 0 11975.5 11993. 5 11990.5 12020. 0 12022.0 12038. 0 12039.5 12045. 0 12045.5 12049. 5 12051.5 12058. 0 12059.0 12061. 0 12062.0 12068. 0 12070.0 12071. 5 12073.5 12079. 0 12080.0 12088. 5 12087.5 12102. 0 12101.0 12147. 5 12146.5 12211. 0 12210.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 5 MWD 7 MWD 9 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 9290.0 10379.0 10379.0 11501.0 11501.0 12210.0 • Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............ .....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9290.5 12211 10750.8 5842 9290.5 12211 ROP MWD FT/H 0.07 1873.66 93.0844 5079 9672 12211 GR MWD API 10.96 864.1 65.5758 5342 9290.5 12187.5 First Reading For Entire File..........9290.5 Last Reading For Entire File...........12211 File Trailer Service name .............STSLIB.001 Service Sub Level Name... • • Version Number...........1.0.0 Date of Generation.......05/11/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/21 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9290.0 10355.0 ROP 9670.5 10379.0 LOG HEADER DATA DATE LOGGED: 10-JUL-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10379.0 TOP LOG INTERVAL (FT) 9670.0 BOTTOM LOG INTERVAL (FT) 10379.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 64.9 MAXIMUM ANGLE: 87.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray 016 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 3.000 DRILLER'S CASING DEPTH (FT) 9667.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.70 MUD VISCOSITY (S) 65.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3) 5.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 158 .6 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 • Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDO50 FT/H 4 1 68 4 2 GR MWDO50 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9290 10379 9834.5 2179 9290 10379 ROP MWDO50 FT/H 0.07 617.45 53.2839 1418 9670.5 10379 GR MWDO50 API 10.96 864.1 47.6899 1679 9290 10355 First Reading For Entire Fi1e..........9290 Last Reading For Entire File...........10379 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/21 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.......05/11/21 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BTT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10355.5 11477.5 ROP 10379.5 11501.0 LOG HEADER DATA DATE LOGGED: 12-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory • TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG 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 • 11501.0 10379.0 11501.0 100.4 86.1 TOOL NUMBER 016 3.000 9667.0 Flo Pro 8.60 65.0 8.5 23000 6.8 .000 .0 .000 171.2 .000 .0 .000 .0 Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10355.5 11501 10928.3 2292 10355.5 11501 ROP MWD070 FT/H 1.22 1873.66 107.534 2244 10379.5 11501 GR MWD070 API 45.09 146.58 77.415 2245 10355.5 11477.5 First Reading For Entire File..........10355.5 Last Reading For Entire File...........11501 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/21 • • Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/21 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11478.0 12186.5 ROP 11501.5 12210.0 LOG HEADER DATA DATE LOGGED: 14-JUL-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12210.0 TOP LOG INTERVAL (FT) 11501.0 BOTTOM LOG INTERVAL (FT) 12210.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.8 MAXIMUM ANGLE: 97.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray 016 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 3.000 DRILLER'S CASING DEPTH (FT) 9667.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S) 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3) 9.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 180.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • C S Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11478 12210 11844 1465 11478 12210 ROP MWD090 FT/H 0.52 1155.02 112.045 1418 11501.5 12210 GR MWD090 API 25.74 263.16 67.795 1418 11478 12186.5 First Reading For Entire File..........11478 Last Reading For Entire File...........12210 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................OS/11/21 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 .....................05/11/21 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
