Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
204-164
L9 - 1 S C r a)O 3 N no V t" ' @ 0 > Q V N Y U CZ r U 0 6 H O O O o O r a) _c c w Z to '' I- > O 2. Y o a) E a p Q-; 0 Q 0 i ir) co U) U) I 'I-' -.F ° N E r co a _ Www o a � aaa � � c VI Y F 2 ONZ J N CD a co N N N E �, m •L c0 2 N O m F- M N M CO h 4 C > a) Z I- s„.. D O O g. o C -- - a1 a., "O L > _c c6 p p p p p p CO U OU C sCr CL W W W W W W to C coo O --- I- LL LL LL LL U. U. 'uf a) E -o N o Q J J J J J J 0. -0 ,O c a) Z 0> Q Z Z Z Z Z Z v VI "O '^ ±:.^,, p U. LL LL LL LL LL - . 0 E _ - L w E 2 a) O 8 ro J Q c O _a c N o c7 Q a1 L Oo > N 0 cd 1. w ry �""`- J F J O J F i+ , p m N p U N TI co R E, O m , � z d m V .5 jrr,rn > (I) CA U) '; J O ; Cv O \ CO IM .. G aCM C) 1 Oh oo CC Ct c- a O J J O O J tn g W U w EL , zaM >+ >. >+ >+ T >+ L 2 ro m m m m m _o Z O O o 0 0 o o p .c s s r .c .c J 'a a -0 -a a a a) - CD LL a a a a a a @ o Ili �q >. iii °� CLO a `✓ v CO0 L- CO In O X o CI o CO LO 0 0 0 _CO MOM d., 0 0 0 0 0 0 )..{ _ 0 0 0 0 0 0 ro 0 !0f' u Cy CO > cccc > E co >x > � w > X p v 000000 TSC x c° co 8 pO N N O V Lo O O O O o O . (. N N N CO V 0) \ I() LO h CO C E i* O COCOIn M N U) h _ N 0 N O V) 0 N d N N N N N N L U - 0 0 0 0 0 c O O NNNNN v� Q1 O O O O O Ocu O O O O O OL In u-) M) In In V() 3 01 CO CO - - O C E Ua) 5 g^o w c U QJ Q �..� k.. Q Q Q co m CO 0 ca a1 3 a m M Z N M N N Y m i ~ Fe Q N -� o LL r p E z v0) co �= i '-I . ^ Y41. C C V o > ami o O C/2 c co H a a Q Iltk;Cnit,L) STATE OF ALASKA 0 Cl1,€ 1 2015 ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS A r (�( ((��'' C 1. Operations Performed 4 Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set Liner Top Packer Il 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-164 3. Address: P.O.Box 196612 Anchorage, Development p Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22012-01-00 7. Property Designation(Lease Number): ADL 0028308 8. Well Name and Number: PBU 02-28A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 11728 feet Plugs measured feet true vertical 8982 feet Junk measured feet Effective Depth: measured 11692 feet Packer measured See Attachment feet true vertical 8981 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"91.5#H-40 33-112 33-112 1490 470 Surface 3454 10-3/4"45.5#J-55 32-3486 32-3486 3580 2090 Intermediate 9268 7-5/8"29.7#L-80 30-9298 30-8342 6890 4790 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10070-10085 feet 10130-10155 feet 10185-10210 feet 10350-10660 feet 10750-10880 feet 11080-11425 11575-11650 feet True vertical depth: 8961 -8967 feet 8982-8986 feet 8988-8988 feet 8988-8996 feet 8992-8987 feet 8982-8980 8977-8979 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 4/S ° -t,U'W 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 169 31910 14 460 1037 Subsequent to operation: 12 26540 1 500 425 14.Attachments:(required per 20 AAC 25.070.25.071,d 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory o Development Eit 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 id cd - Phone +1 907 564 4424 Date 9/22/15 Form 10-404 Revised 5/2015 r7-- /o/7—if 5-- RBDMS JG OCT 0 5 2015 Submit Original Only 001 10/17%d- • • Packers and SSV's Attachment PBU 02-28A SW Name Type MD TVD Depscription 02-28A PACKER 3747.08 3746.5 5-1/2" BAKER ZXP PACKER 02-28A TBG PACKER 8781.5 7932.24 3-1/2" Baker SABL-3 Packer 02-28A TBG PACKER 8914.37 8037.39 3-1/2" Otis BWD Packer 02-28A PACKER 8975.37 8085.61 2.7" Liner Top Packer 02-28A PACKER 8989.43 8096.72 5-1/2"TIW Top Packer • • C) Q.O O O O co O O M co R O 6) O) 0N0 O O f� a7 N ,t t co O O U y 0 0 0 0 0 0 0 i 0 co 6) O O M IC) co 3 10 CO O N- N- LU O N CO N O N CO N CO O - O) N M O 6) CO N O) •- M CO 00 CO CO N I- 00 IIIIIIIII I- CO N N- V LU M N O CO O O CO CO CO CO I- O O N N O M CO 00 N 00 as CO 00 N O v In u) CO O V N CO 00 N CO O CO O CO 6) N CO O V I I ICO CO co a) moi' CO Q N M N O c"') co co 00 - co M M M I- O) a1 N N co CO N M co co N co M co a c, Lo co 00 O O c2 coco0Uao ,r J J J J M M N 4t lO M U MCO C\ M C 4 L ++ 0o CO L() co co LU M L V , 00 .4 M C N- N ' N J M O lO N N CO W O C I- W W CO 0 U U D u rYa c Z Z Z zWWWmmm O D H z z_ z_ D 0 (n Z J J J H H E- • • • w c -D J o 0 0 o v Q 2 Cl) 0 WO - a col, w r o J r O J c _ * J 3 CD 0 w o O U O 17-. " 0 Oa ami O 3 C0) O 2 d 3m U O °� o Q p 0_C) T J a a J73 * W E c '- - 4 O � J c O 0 O_ p mU C) a -O o, O cn U) a- in o n Y o� N O• U) 0 i W DZS N a 2 H 1 Q - 0) JJ c 0 CO OI- Z a --=- o 'rn a0 - ° F- _a W m '- a O p a O u) 2 M _ 0 O � 0Hz E � D fX J)= oO as c0 OO > WC _J 000 ! JO cOO O J J Y 0, 0) c N0 O c Q o - oQm N Q J QJpNpm 6 ,6 UDo N ) � DO - ODON � E a � w ) L4 p OZo 0 . O m f- a 76 5 ao _ .=. m o ii o22i" c E _1 Q2Qm 0_c) a6, o JO ( CNnan O NC OWn OUO O M Cl- Qom * LL O. Lo cc Z Q O a m a cm w J * o M o 0 3 o ~ o * o a w a CD QW � � 0 � � � CD p mo >>am2ZOQO ' JO Zo›+ 0 � o � E Qo ° - opp ( EEm mOJJ� 0Hw �mW C O E u) O - >- OH m _lo � � 2J � Zm � O3- - .-- 1_ m - ,-, c nHL0wOrn0mm Orn ac .2 `" 0OZOZ fZo � � XZOa - O X Z > w � W = inZOOW } 0o S acW OWW O N W a () W O Z D ~ O J C C c D W Q j C - D � JZ_ Z 12 F � � HZ_ pQ Q* 0j OZ_ � O _Z OQ 2 ZWOJ � Z _I I- - Xp _)` < 0O Eto O O -0I- wJ - UU_ O ~ Ym0 wm0 O `'' ff ` E 'L' ocnpav () 40 � 0 (4 � � omEIN " O * * * Q >Q O Q * * 0 * -0 o * w c[ * 3 0 � * Q W w w * * a' * * a C7") a a * * 2 o * N c- * > J * * 2 * a' 0 w w * W H N- >- O o o O O o 0 N N N N N N N 5- N 00 co 4 4 in I= 0) W O O 0) W 0 Q . 0 E2 \ 7 W \ / « ± \ 2 U U) e = e Cl) us ._ .o = < 2 E \ 2 LT , -.--, 2 .c o = \-c (7) \ p § > $o i / / I o 0 A o < = 0 £ / $ 0 % / CI ® $ m / R ¥ 5 f m Co / > o_ 0 eo - O L C m_ D u_ DII I co cti o f \ o / 0 E o < y / ± q 7 Z = c 0. - / _ % - o d u ® 0 « 2 / R c E 0 $ k/ - o 0—= 3 o / � � f� �(73\ / oM t W-0 \ $ : 0 \ r G E § 2> G \ 2 -I \ ,— O. GI .§ R % \ / / \ 0 @ 9 c a 2 r 2 >, c0L7 � kkkc2 k E Q 7 = o - c < - 0 < 1• . °- 0 < 00-c3 — _ O2 ± O mo@m § O 1 I ± I -I ¥ONo > LaII ±22In' $ DO / j // 222 ± gym± = a _1 3 $ I L a CL _1 O -, \ / a O \ III ) © e e 5 (t .a EUm -IR � tea = I- : - O/ f i \ 0_ $ f / ,- / / r r ,-- \ - co e o co c a a IlLTREE= + 4"CNV • i NOTES: WELL ANGLE >70'@ 10114'"" WELLHEAD= FMC ACTUATOR= BAKER C 02-28CHROME TBG*** NTIAL KB.P F 62.0' BF.ELEV= KOP= 4100' 2182' -j4-112"FE'S X NP,H]=3,813" Max Angie= 95'©10756' Datum MD= 9914' 2213' H4-1/2" X 3-1/2"XO,D=2.992" Datum TVD= 8800'SS 4-1/2"TBG,12.6#,13CR-80 VAM TOP, -i 2213' 2985' -i ESTMATED TOP OF CEMENT .0152 bpf,ID=3.958" ,1,1 1114 _ 1/ 0, GAS LFT MANDRELS 10-314'CSG,45.5#,3-55 BTC,ID=9.950' -f3485' ST MD ND DEV TYPE VLV LATCH PORT DATE 7-5/8"X 5-1/2"BKR C-2 ZXP LTP 3734' 1 3365 3364 1 HMG DOME RK 16 05/28/08 ►I 2 6110 5820 37 KBG2-9 SO INT 20 11/04/08 w/11'Tl ACK,D=4.890" 0' 04 HGR D=4.970" -{ 3752 7-5/8"X 5-1/2"BKR FLEX LOCK 1 , i °4 s,, ►4 ►4 7-5/8"CSG,29.7#,L-80 ABM BTC XO TO L-80 BTC --,1 4689' ►� ►� 8748' H 3-1/2"FSS X NP;D=2.813" ►4 �4 Minimum ID = 1.50" @ 8972' :4 D&D LTP ASSYwITBG STOP j %►5 ►5► i8780' -5-1/2'X 3-1/2'BKR S-3FKR,ID=2.780" j 0 8811' --3-1/2"FES XN MP,D=2.75" 5-1/2'MARKER JOIN -j 8830' W 0 ►4 4 ► ►� 0 3-1/2"TBG,9.3#,13Cf� • HOE D=2.992" 80 VAM TOP, -j 8854' j ►� P., 8854' --j3-1/2'MULES 0087 bpf,D=2.992" 0�•Of •••�•� 8857' --15-1/2"X 3-1/2"XO,D=2.992" 41, 5-1/2"SCAB LNR, 15.5#,L-80 BTC-M, -{ 8857' ' i .7•; X 8891' H7-5/8"X 3-1/2"CSG OVERSHOT,D=5.375" .0238 Bpf,D=4.950' ►i�• 'ei �•IP. •11A 8917' H4-1/2"OTIS LOCATOR SEAL ASSY,D=2.97' 3-1/2'TBG STUB(05/02/08) 8885' iii ói:i 8918' -7-5/8"X 3-1/2'OTIS BWD PKR,0=4.00" 110-M11 EN 3-1/2"D&D LTP ASSY w!TBG STOP H8972' 8937' 5-1/2"ML.LOUT EXTENSION,D=4.35" h D=1.50"(9/6/15) = 8945' -5-1/2"X 3-1/2"XO,D=2.992" TOP OF 2-3/8'LNR --1 8983' 8983' -j 2.70'BKR DEPLOY SLV,D=2.250" 1 8990' -12-3/8*XO FIN,0=1.995" TOP OF 5-1/2"LNR 8993' r, 8993' - 7-5/8"X 5-1/2"TLTP w/HGR,D=4.802"1 EE 3-1/2"TBG-FC,9.3#,L-80 E-8RD, - 9029' Mt 9017' -13-1/2"OTIS XN NP,D=2.75'(BB OND PIPE) .0087 bpf,D=2.992" 7-5/8"CSG,29.7#,L-80 BTC,ID=6.875" H 9301' 9029' H3-1/2'VVLEG,D=2.97"(BEHIND PIPE) 5-1/2'WHPSTOCK(11/28/04) H 9835' 9027' H ELME)TT'LOGGED 05/08/90 PP TAG H 9842' PERFORABON SUNVARY �.1.1 •'•f' 9600' -{TOP OF CEMENT RTF LOG:SWS MEMORY CNJGR/CCL ON 12/11/04 f11/ ///f1 ANGLE AT TOP PERF: 62"@ 10070' f111 �1�� MLLOUT VW"DOW(02-28A) 9839'-9845' hbte:Refer to Production DB for historical pert data �'.•*4. SIZE SPF INTERVAL Opn/Sgz SHOT SQZ #��4:�4. 1-9116" 6 10070-10085 0 08113/13 , 1-9/16' 6 10130-10155 0 08/13/13 1-9/16' 6 10185-10210 0 08/13/13 1///�/1AMPAM♦11, 1-9116" 6 10350 10660 0 12/11/04 114444411414/ PBTD 11692' ' 1-9/16" 6 10750-10880 0 12/11/04 1-9116" 6 11080-11425 0 12/11/04 1-9/16" 6 11575-11650 0 12/11/04 2-318"LNR 4.7#,L-80 STL, --{ 11728' j &N. 5-1/2"LNR,17#,L-80 FL4S BTC,.0232 bpf,D=4.892" H 10216' .0039 bpf,ID=1.995" -0, DATE REV BY CXMA4ENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/17/90 1428E ORIGINAL COMPLETION 08/30113 I IRR/JMD ADPEFFS(08/13/13) WELL 02-28A 12/12/04 NORX C1 CTD SIDETRACK(02-28A) 10/01/15 N-W/JMD SET PACK OFF ASSYRBG STC PERMIT No:'2041640 05/18/08 N2ES RWO AR No: 50-029-22012-01 06/25/08 SCG/PJC GLV CORRECTIONS SEC 36,T11 N,R14E,273'FM.,&796'FWL 11/04/08 JLJ/SV GLV C/O 11/20/08 TMP/PJC DRLG DRAFT CORRECTIONS BP Exploration(Alaska) • • Z Csr 2-i% //t® PRINT DISTRIBUTION LIST BAKER tb-56 . 05-02A Please sign and return one copy of this transmittal fc HUGHES o2:21A. 0\-1.9 (mandatory) ©1.-1 Co Petrotechnical Data Center, LR2-1 DATA LOGGED WELL NAME 5 DIFFERENT WELLS 900 E. Benson Blvd. I. /2/2015 M.K.BENDER (mandatory) Anchorage, Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. (mandatory) COUNTY North Slope Borough LOG TYPE RPM-Wireline (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: September 3,2015 TODAYS DATE: 24-Sep-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: CANIZARES EMAIL: (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY A B C D ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) L.I.S. FILM PERSON ATTENTION #OF PRINTS_#OF COPIES#OF COPIES#OF COPIES#OF COPIES#OF COPIES L 1 4 U U 4 4 1 ConocoPhillips Alaska Inc. 1 1 1 _ 1 Attn:Ricky Elgaricio A= 05-02A_RPM_PNC3D_RAW_03SEP2015_BH I.meta ATO 3-344 700 G Street Anchorage,AK 99510 B= *(Folder 1 on cd/dvd) 05-02A_RPM_PNC3D_RAW_O3SEI 2 ExxonMobil,Alaska R E�1 E e D I 1 1 1 Attn:Lynda M.Yaskell and/or v Leonardo Elias SEP 2 8 201' 7 )r} 3700 Centerpointe Dr.Suite 600 j SCANNED AUG 1 2016 Anchorage,AK 99503 AO♦1�1(`"/I( N1��� 3 State of Alaska-AOGCC ��,�I 1 I 1 1 1 'Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 1 4 DNR-Division of Oil&Gas 0 I 0 I 1 I I Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 5 f I I L TOTALS FOR THIS PAGE: 2 1 1 1 0 0 TOTALS FOR ALL PAGES: 2 1 1 1 0 0 · . 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. J. 0 Lf - 1 0 Y- Well History File Identifier Organizing (done) o Two-sided ""111111111"1111 o Rescan Needed 111111111111111111I RES CAN ø'Color Items: o Greyscale Items: DIGITAL DATA ~iskettes, No. ~ o Other, Noffype: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Date d 17 /Q7 I I 151 ú1P 1111111111111111111 Project Proofing BY: ~ 151 ~ Scanning Preparation BY: Production Scanning Stage 1 Page Count from Scanned File: 7 J. (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date:-t/17/07 11111111I111111111I NO 151 VV\ r NO Stage 1 If NO in stage 1 page(s) discrepancies were found: YES BY: Maria Date: 151 11111111I11I1111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 1I111 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 if t.„, W i re r L 4 iketi August 22, 2011 406 I � o,� 4/4 Mr. Tom Maunder � � � sec . Alaska Oil and Gas Conservation Commission 11, • 333 West 7 Avenue '� � S s trj Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -02 01-1-- I 2 11 Dear Mr. Maunder, 0 may D_,qc Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir 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 -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -066 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A r NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 ( .). 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -326 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B r 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 OPERABLE: 02-28A (PTD #2041640) Tubing Integrity Restored Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] fK l ~l/2~~Z~`~', Sent: Thursday, November 06, 2008 8:53 AM l To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater}; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr; Aspelund, Roger E Cc: Holt, Ryan P (ASRC); Rico Hernandez, Claudia; GPB, Gas Lift Engr; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 02-28A (PTD #2041640) Tubing Integrity Restored AI I, Well 02-28A (PTD #2041640} passed a TIFL on 11/05108 after the gas lift valve in station 2 was changed out. The passing test verifies that tubing integrity has been restored. The well as een reclassified as Operable. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, October 26, 2008 1:22 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FSl DS Ops Lead; GPB, FSl OTL; GPB, Area Mgr East (FS3/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr; Aspelund, Roger E Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Rico Hernandez, Claudia; GPB, Gas Lift Engr Subject: UNDER EVALUATION: 02-28A (PTD #2041640) for Sustained casing pressure due to TxIA Comm Hi all, Well 02-28A (PTD #2041640) has been found to have sustained casin ressure on the IA. The wellhead pressures were tubing/IA/OA equal to SSV/2200/0 psi on 10/26/08 when a IFL was conducted and failed, confirming TxIA communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. Operations may allow the IA pressure to continue to build pressure. The plan forward for the well is as follows: 1. DHD: TIFL -FAILED 2. Slickline: Change out gas lift valves 3. DHD: re-TIFL A TIO plot and wellbore schematic have been included for reference. ~ 11/28/2008 OPERABLE: 02-28A (PTD #2041640) Tubing Integrity Restored Page 2 of 2 • i Please call with any questions. Thank you, Anna ~Du6e, ~? E. Well Integrity Coordinator GPB Wells Group Phone: {907} 659-5102 Pager: (907} 659-5100 x1154 11/28/2008 ~t ~ ~ d i N c~ ~. t~ i r"' ~L' ~- ~C ^ T~. ~ ^ ^ ~ =1 Q ° ° ° o a_ o_ o_ {rJ (~ T 0 a 0 0 0 0 a a a 0 r 0 u, rn a a rn 0 0 a a 0 ~, 0 0 co a ~v r~ T~EI`- 4-118" GAT~7ERnPd WELT tICALt- FM!: ~. _ ..~ .~ AC-fL3ATGFt= ... - _ ___r AXf~LSCJt1 KB. ELEV = 62.0` ~E ELFV tU13x Rnctle = . . ~J;~ {~ 107af~' . .. _ .. CYatu tf i IBC} _ 990~~ E)atum-fVD- 68C0'SS ~-. ~~ 4-t l ~° T6C;-PG,12.6#. i3CR, .Q152 bPf, ~i = 3.958" H 2212` ~ST3 TFd GMt' TC1P ( 29$5' 9D-3d~ ~'SCa, 4.~i Wit, J-55. {C1 ~ <#-_r~,53,• 34$5' SAE OTES: IA GEL SQZ {5970'-6050'). '*"PROa CSG -: -~°~ = LEA TING LIMITS: MAX iAP = 500 PSI, MAX OAR '~ F - = 1000 PSI {02!20/06 WAIVER)*** .-a ~ ~ a DON'T RUN LGLV`s, IA LOADED WlBRINE OVER GRET LEAK. 70° @ 10096° 2182' ~t-if2" X IkIO', IC#=C,892" 2213' ~4 t F7° X .~-112" xo, tD = Z.S6T, ta,AS LIFT i+AANt7RE•15 5T SAD TU'L9 L3EV TYPE VLV LATCH PnRT' DATE 1 :i3C~~ 61 t Q 3304 582(1 1 37 fil;{vH'~ KB{~-2-`3 C)OtJlL S!(.} f~K fhJT 1~a 2{i (l5/28;Q8 OSI'?BICi$ - 373~F1' --~7-~?8" X 5-112" Packer T-5t8" G5G, 29.7#„ L-$0, = 6.S7a" ~#i89' 5-112" 17~, L-, STL, ID = 4.892" - 8857 5-112"' x 3 1 t2" Parted XO 8$57~~ Top of 2 x 10' 3-1.~ Pups 8$58' 7-~/&" x 3 'i,`2" Overshot $&91' 3-12" Stub tp = 6,Sr'S«' 8f385' ~iOP QF 5112" LAJ~ 1~1 ,8993' Nf~lnitrrltsm ~C? =1.92" ~ X99{3" ~., , ~,,. ,-8t~~t, ~., L-8~1, .$'~ bpt, = 2.992" F--{ 9028' 7-518`° C sfi.~, 23.7, E»-SD, fC1 -- 6.~r°.~-," {-~{ ~3(jQ' (TtaP OF C;FTt9Fl~ft" ~--~ 9st~o. 5-112" WH~TOi.K {1 i ; SO~ij 9835' ~C'PTAG 9$42` ~~3-~~~~~t~~ -- - :rU~,.• LP,a12, 1 T#1, L h0 f?23"? t~pf, IL rt 3y?^ _ 10216` ~ef~F~}r~~r~rt)~t~~ RLi- 1 C7~: SW; 4df3}:'IOP2Y Ct`iL'Gf G~i_ ON 1 ?11 i 1Lt4 r°+t•ai>f_f AT T(;F' k~~RF: t37 ~7i it??~4' P,);~te: ~t?~`~r tc~ Frc~duct)ort Df3 fr~r EFislcricaf perf data ~iLE F'%= [Pdit_F'11n.L Usti%5r,~ Ur~T"! r 1 'c>r 1 Ci" E 4 0350 - ; 0+?~.i) O 1 ! 1 . ; tJ~{ 1-r}''16" 6 1 t3; ~~ t Or3ftJ O '_ '1 1 ri}4 1 [}i 1 ~ ~" Ei 11 Cl~iu' - t . =~"?5 Q 1 F'1 1 i0~1 1-~3ri{~,. 8 di575°ilfi tJ i~r11;2:} $?~i7' --~3-1 2 X i`1ip I[~ = 2.813 ` 878Q' 5-112 X 3-t/'~ [3aker ~'A r:l .~ .'.,Ft F'KE2 8$i'I` 3-112" XPJ gip- id = 2 r S" 8918. ~(7-~~t" X 3.-7 rz° u~te aver, PAP, tg = ~_eo , $9$3• -~-~"~.l0'$KRDEPl,[~Y SLV, I0-?.2511" ~ 3`112" OTtS XN Nom, ~ = 2.75'• {Bt3-t1N1`1 P1Pq ~ _~(}~$~ 3 1t`" 4^.!C.EG. !C)-2.Gi" {BEJ-{lFJC1PIPF~ '~f12~' Et l`vt,~ T`C LFJt~~Ep0`' L'9~`9t1 -- -- ~ - MiL.Lt;.IUT WiNC}CiW {t?2-213Ay 9$39' - 9845` PeTi9 --~ 1159 7-~ 8 LtaR, ~ .??, L u0 °TL, U(~3 b}~f, k~' 1 .995" ~~ '~ 1728' [~A "E F:EV BY r:C~t~V+~~EDJTS D?1E REt! BY Ei^tTS oa~~~r~o __ ORiGtIVA1.. Ct3Px1PC.EYIOP~J __ 12l121D4 is}pi~iG1 GTDi1CYETRACi'~{0;?-2$A,) f)5?is(Q8 At2~5 R'YdO G~?3;'03 K,JEr;',1G GLV CC~HFtI=CIIQN {15/28;,.8 KS$tTi7 GLV Glf:1(5f281Q$) {J51251{18 SCGIP,IC GLV Gt~RREG11C1N -. ____. ARL1DtG ~,.~ y t )glrr 'WELL. No: 2t';i6 , A F~ i~kcr: 5t? ~"5~ ' ';' 1" ?i SEC 3, T11 td, R14E, 2122::" ~ °°:7.19" ~NL BP Exp~lorafipn {Ataska3 STATE OF ALASKA ~~~; ~ $ 200$ ALA OIL AND GAS CONSERVATION COM ISSION REPORT OF SUNDRY WELL OPERATIOI~'~ka (?i! ~ ~a~ ~~,.,~ ~~~~~,~$~~~~ ,:, _ 1. Operations Performed: ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing ®Pull Tubing , ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exp-oration (Alaska) Inc. ®Development' ^ Exploratory 204-164 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22012-01-00 7. KB Elevation (ft): 62, , 9. Well Name and Number: PBU 02-28A 8. Property Designation: 10. Field /Pool(s): ADL 028308 ~ Prudhoe Bay Field !Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11728 ~ feet true vertical 8982 feet Plugs (measured) None Effective depth: measured 11692 ~ feet Junk (measured) None true vertical 8981 ~ feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 3488' 10-3/4" 3488' 3488' 3580 2090 Intermediate 9301' 7-5/8" 9301' 8345' 6890 4790 Production Liner 1223' S-1/2" 8993' - 9839' 8100' - 8801' 7740 6280 Liner 2745' 2-3/8" 8983' - 11728' 8092' - 8982' 11200 11780 Scab Liner 5157' S-1/2" 3734' - 889 1 ' 3733' - 8 019' 7000 4990 p*~~RR~~ ((',~ j ~ e~~ld'OIYItlE® QUU ® L'~ Q 2oOV Perforation Depth MD (ft): 10350' - 11650' Perforation Depth TVD (ft): 8988' - 8979' 4-1/2", 12.6# x 3-1/2", 9.3# 13Cr-80 9028' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 5-1/2" x 3-1/2" Baker SABL-3 Packer 8780' 7-5/8" x 3-1/2" Otis'BWD' Packer 8918' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 8888'. Run 5-1/2" (15.5#, L-80, BTC-M) Scab Liner with 7-5/8" x 3-1/2" overshot to 8891'. Cement w/ 56.4 bbls Lite Crete 317 cu ft / 95 sx and 53.8 Bbls Class 'G ' 302 cu ft / 260 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to we-I operation: 0 0 0 20 242 Subsequent to operation: 660 8861 36 560 271 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Travis Peltier, 564-4511 308-100 Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Si ature - Pone 564-4750 Date °Ci~Sondra Stewman, 564-4750 Form 10-404 Revised Q4/PQO~ ~ ~ ~ ~ ~1=~; A(J~ ~ ~. ~~fl~ Submit Original Only ((lJ~l KK A L ~-~r~ TREE = X4-1 J8" CANTER©N WELLTtFJ1D- FMC ACTUATOR = AXELSON KB. ELEI/ _ ~ 8F. CLE~1 _ _ 52 0 ._.. ,.. KC3P = __ ~ ~._n Iv1ax Angle = 41 QQ' ___v 95 @ tQ154 Batum Mp - Batum 111!3= _ 9908' }3;300' S$ • ~ 4-1 /2" TBG-PC, 12.f#, 13GIZ, .11152 hl5f', ID = 3.958" I-{ 2212' ESTIMATED CMT TOP 2985' 10-3f4" CSG. 45.5# 1-55, 1D = 9.953" X485' SAFETY NOTES: IA GEL SQZ (5970'-6050'). "'"`PROD CSG t LEAK OPERATING LIMITS: MAX IAP = 500 PSI, MAX OAP "'~ r,n ;,, = 1000 PSI (02120/06 WAIVER)*** DON'T RUN LGLV's, IA LOADED W/BRINE OVER CRET LEAK. 70° @ -10096' 24$2' 1~41IZ" X NIP, ID = 3.812" ~~2Z43' -4-1;2" X 3-112" XQ ID = 2.867"' GA S LIFT MA NDREL5 ST MD TVL} DEV TYPE VLV LATCH PORT DATE 1 33fi5 3364 1 MMG Lk>me RK 16 05128108 2 6110 5$ZQ 37 KBG-~ SlQ INT 2p p5/281Q$ - 5734' 7-518" X 5-1 i2" Packer 7-518" CSG, 29.7#, L-80, ld = 5.875., 4689,=`~ ~~~5-'t l2" 17#, L-8~, STL, 1D = A-892" $$57~ 5-112" x 3-112" Parted XO 885T Tap of 2 x 10' 3-1 r4' PUps $$ 58' ---- 7-5f8"' x 3 1 /~ Overshot 8891" 3 112" Stub 3D - 6.875 888' OF 5-1 d2" LNR I'-`I 8993' Minimum ID =1.92" i~ 8990' 7(?P OF ~-318" LINE R 3-112" TBG-PC, 9.311, L-8fl, .otl8a bpf, = 2.892'• H 9C}28" 7-51s" csG, 29.7#1, L-$o, ID = 6.875" I-{ 9300` TOP OF CEMErJT ~ 9600' 112' WNiPSTOCK (11128104} __9$35' P1P TA G 9842' PBTD -~ 711767 5-1 /'~*" LNR 17#, L-80, .0232 bpf, ID - 4.892" 18216' -- 10221' PEF{FORA TtC?N SUMMARY REF LQG: SW5 MEMORY GNLIGRlCCL 4)N 12111!04 ANGLE ATT~P PERF; 87 @ 10350' Note: Refer to Production DB for histar~al perf dsta ... ........ SQE SPF CNTFRVAL .... OpnlSgz DATE 1-9115" 6 10350 - 1 Qfi60 • O 121111(14 1-9115" 6 10750 - 1088Q O 12!11144 1-9115" 6 11080 - 11425 O .12111104 1-911fi" 6 11575 < 11650 O 12111104 8747' H 3- C2" X Nip, ~3 - 2.813" 1!2" Baker SABL-3 JCR PKR 87$0' 5-112 X 3 8811' 3-1/2 XN Nip IL3 2.76" 8918' 7-5/8"X3-112" OTIS BWD PKR, ~3 = 4.04" 89$3' 2.70"' BKR DFF'LOY SLV, ID = 2.250" (3-112" OTtS XN N, 1D= 2.75" (BBiINDPIPk'} I g02$' ~ 3-t 12' WLEG, Id = 2.97" (BEHIND PIPq 91;}27" ELMD TT LOGGED 05108!90 MILLOUT WINDdW (02-28A) 9839` - 9846' PBTD 11fi92' LNR, 4.7#, L-80 STL, .(1038 hpf.1D = 1:995" '~ 172$' _QRTE REV BY rOMMENTS DA°fE REV BY COA+14tiENTS 03/17/90 012IGINAL CQMPLETION 12112104 NORDICI GTD SIDETRACK (112-28A) 05/18/08 ht2ES RWO 05/28108 KJB1P,lG GLV CfJRREC710N 05128148 KSgITD GLV GO (5r28(0$) PRtJDHOE BAY UNiT WELL: 02-28A PERMIT No: 2D416S0 A P[ No: 517-0~-22012-Q1 SEC 3, 711 N, R14E, 2122.28' FEL & 3777.19' FNL BP Exptnratian (Alaska) Digital ~JVell File Weli: 02-28 Well History Well Date Summary • • 02-28A 4/5/2008 ***WELL SI ON ARRIVAL*** (sbhp) RAN 1.90" PORTED SWAGE, S-BAILER (SAT DOWN ON DEPLOY SLV C~ 8969'SLM + 14' cor.= 8883'MD RAN 1.75" CENT., 1.50" S-BAILER, DRIFT DOWN TO 10116' SLM + 14' corr. = 10130' MD. TLS STOP DUE TO DEVIATION. RAN SBHP SURVEY AS PER PROGRAM -GOOD DATA RECOVERED -SEE DATA SEC. FOR INFO. ***TURN WELL OVER TO DSO -WELL S/I ON DEPARTURE*** 02-28A 4/19/2008 T/I/O=SSV/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test void to check pressure (0 psi). Pumped through void until clean fluid returns achieved. Pressured void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Functioned LDS (ET style), all moved freely no problems. PPPOT-IC: Stung into test void to check pressure (0 psi). Pumped through void until clean fluid returns achieved. Pressured void to 3500 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Functioned LDS (ET style), all moved freely no problems. 02-28A 4/25/2008 *** WELL S/I ON ARRIVAL *** (pre rwo) RIH WITH FLAPPER CHECKER AND VERIFY TRSSV IS OPEN.. *** CONT ON 04/26/08 WSR *** 02-28A 4/26/2008 ***CONT FROM 4-25-08*** (pre rwo) DRIFT W/ 2.84" NO-GO CENT & S-BAILER TO 89$3°_~(n G SET 2-7/8" CAT STANDING VALVE C~ 8983' MD (see log for specs) DUMP BAILED 50L6 BAG (sluggits) FROM 8979'-8971'SLM. 8 FT OF SLUGGITS. SET HO DAP TOOL IN TRSV ~ 2186' MD (see log for specs) DRIFTED W/ 2.86" CENT TO 2500' SLM BLEED C-LINE TO 0 PSI. NO RESTRICTIONS. PURGE OUT CHEMICAL INJ LINE W/ 8 GAL HYD OIL. ***TURN WELL OVER TO DSO -WELL S/1 ON DEPARTURE*** 02-28A 4/27/2008 ***WELL SHUT IN ON ARRIVAL: T/I/0=1900/0/0*** JET CUT 4-1/2" TUBING AT 8 888' W/ 2.5" POWERCUTTER. SURFACE CONFIRMATION OF FIRING. WELL LEFT H _ ***JOB COMPLETE*** 02-28A 4/29/2008 T/I/0=1900/100/0 Temp = SI Circ out, MIT OA PASSED to 2000 osi (PRE RWO) Pumped 5 bbls neat meth, 667 bbls of 9.9 ppg NaCL brine down TBG taking returns up IA to flowline. Freeze protect well w/ 21 bbls diesel & U-tube Tbg to IA. Freeze protect flowline w/ 7 bbls neat meth & 98 bbls crude. MIT OA to 2000 psi passed on 3rd attempt. OA lost 40 psi 1st 15 mins, OA lost 20 psi 2nd 15 mins for total loss of 60 psi 30 mins. FWHP's= 0/0/0 ***Annulus valves tagged and open to gauges*** 02-28A 4/30/2008 T/I/O=Vac/0/0; Set 4-1/16" FMC IS-A BPV # 511 thru tree pre 2ES rig move; No ext. used, tagged 108" ***Complete 02-28A 4/30/2008 ***WELL S/I ON ARRIVAL*** FLUSHED CHEMICAL INJECTION LINE W/ 25 GALLONS HYDRAULIC FLUID ***LEFT WELL S/I DSO NOTIFIED*** 02-28A 5/1/2008 T/I/0= 0/0/0. Pull 4" FMC ISA BPV thru tree. Rig move on well. 02-28A 5/2/2008 Pull 4" FMC ISA BPV thru BOPE after testing. Nabors 2ES 02-28A 5/12/2008 ***NABORS 2ES RIG SUPPORT*** RAN 2.75" LIB TO 8992' SLM...LIB SHOWS POSSIBLE IMPRESSION OF G-FN. ***CONT. JOB ON 05/13/08 WSR*** 02-28A 5/13/2008 ***CONT JOB FROM 05/12/08 WSR*** (nabors 2es rig support) RAN 2.84" CENT & 2.25" TAPERED LIB TO TOP OF STANDING VLV C~ 8992' SLM LIB SHOWS IMPRESSION OF SCREEN INSIDE OF G-FN ONLY. ***TURNED WELL OVER TO NABOBS 2ES*** 02-28A 5/14/2008 ***NABORS 2ES RIG SUPPORT*** (rwo expense) RAN 2/84" CENT & 2.25" T-LIB TO 8982' SLM, IMPRESSION OF 1.551" MILLED HOLE INSIDE OF G-FN (no screen) OF CAT STANDING VLV. RIH W/ 1.583 GRAPPLE ON A BAITED BOWEN SPEAR TO 8982' SLM. GOT SEVERAL SMALL FRICTION BITES. METAL RING ON NOSE OF BOWEN SPEAR, NO MARKS ON GRAPPLE. ***CONT. JOB ON 5-15-08 WSR*** http://digitalwellfile.bpweb.bp. com/WIInfo/Reports/Report Viewer. aspx Page 1 of 2 6/18/2008 Digital `vVell File • 02-28A 5/15/2008 ***CONT. JOB FROM 05/14/08 WSR*** ***NABOBS 2ES RIG SUPPORT*** (rwo expense) RAN 2.84" CENT. & 2,75" T-LIB, IMPRESSIONS OF 1.551" MILLED HOLE INSIDE OF CAT STANDING VLV G-FN. RAN 6' x 2.25" P-BAILER...MINIMAL RECOVERY OF FINE METAL SHAVINGS. RAN BAITED BOWEN SPEAR (1.556" grapple) TO FISH @ 8982' SLM...METAL MARK ON NOSE OF SPEAR (.70"). RAN BAITED PRONG W/ BR. LINE AND BRASS TT PINS TO SAME, 3/4" - 2" OF PRONG IN FISH. RAN BAKER TAPPERED SPEARED TWICE TO SAME, WELL WENT ON VAC AFTER 1ST RUN. RAN SPRING LOADED SPEAR W/ 1.51" GRAPPLE TO SAME DEPTH, UNABLE TO PLANT. ***TURNED WELL OVER TO NABOBS 2ES`** 02-28A 5/17/2008 ***NABOBS 2ES RIG SUPPORT*** (rwo expense) PLANT BAITED BOWEN SPEAR (1.583" grapple) IN STANDING VLV @ 8978' SLM. PULLED CAT STANDING VLV FROM 8978' SLM. DRIFTED W/ 4.6" GAUGE RING TO 5-1/2" x 3-1/2" XO C 8867' SLM. *** WELL TURNED OVER TO NABOBS 2ES *** 02-28A 5/18/2008 T/I/0=0/0/0; Set 4-1/16" CIW "H" BPV #111 thru tree for 2ES Completion; 1-2' ext. used, tagged @ 102 ; Set 2" FMC pug in omp e e es o am 02-28A 5/18/2008 T/I/O=Vac/0/0. Pull 4 1/8" CIW "H" TWC thru the tree for completion. 1 - 2' ext used. Tag @ 98". 02-28A 5/20/2008 T/I/0=450NR Plug/150. Pulled 4" CIW "H" BPV #111 thru tree, post rig. 1-2' ext used, tag C~3 100". VR Plug still in I/A. 02-28A 5/20/2008 T/I/0=450/300/150; Pull VR plug out of I/A post 2ES 02-28A 5/27/2008 ***WELL SHUT IN ON ARRIVAL*** PULLED BALL&ROD FROM RHC BODY @ 8794' SLM ***JOB CONT. ON 5/28/08*** 02-28A 5/28/2008 ***JOB CONT. FROM 5/27/08*** PULLED 1.5" DCK SHEAR VALVE FROM STA #1 Cam? 3365'MD PULLED 1" DGLV FROM STA.#2 ~ 6110' MD SET RK-DOME GLV IN STA.#1 @ 3365' MD UNABLE TO SET 1" BK-OGLV IN STA.#2 @ 6110' SLM, DEBRIS RECOVERED ON GLV RAN POCKET POKER IN STA.#2 @ 6110' MD ATTEMPTED TO SET 1" BK-OGLV IN STA #2 -VALVE APPEARED TO BE ALL THE WAY IN POCKET. RAN POCKET POKER/BRUSH TO STA #2 AND BRUSHED FOR 1.25 HRS -HAD TO BEAT BRUSH BOTH WAYS THRU GLM. TT PIN MISSING. ATTEMPTED TO SET 1" BK-OGLV IN STA #2 -VALVE SLIPPED OUT -MARKS ON VALVE APPEARED TO BE IN POCKET -RESEARCH WELL -ORDER 1" INT GENERIC OGLV. SET 1"GENERIC (20/64") - INT IN STA #2 @ 6100'SLM. (6110'MD) PULLED 3 1/2" RHC FROM XN Cam? 8801'SLM (8810'MD) -EMPTY. *** TRUN WELL OVER TO DSO -LEFT WELL SHUT IN -CONFIRMED THAT DRIFT WAS NOT NEEDED W/CO REP *** ***SCHEMATIC & RIG HAND OVER SHOW BK LATCH IN STA #2. STA #2 IS INT LATCH.*** Print Date: 6/18/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer. aspx Page 2 of 2 6/18/2008 • • BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: 02-28 Common Well Name: 02-28 Spud Date: 2/27/1990 Event Name: WORKOVER Start: 4/28/2008 End: 5/15/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/18/2008 Rig Name: NABOBS 2ES Rig Number: Date 'From - To Hours Task Code', NPT ' Phase Description of Operations 4/30/2008 20:00 - 22:30 2.50 RIGD P PRE PJSM. Blow water and steam down. Unplug pits, camp, and /1/2008 22:30 - 00:00 00:00 - 01:30 01:30 - 04:30 04:30 - 05:30 05:30 - 06:30 06:30 - 08:00 08:00 - 12:30 1.50 1.50 3.00 1.00 1.00 1.50 4.50 RIGD MOB MOB RIGU RIGU RIGU RIGU P P P P N P P IT PRE PRE PRE PRE PRE PRE PRE shops. -Bridle Up and Lower Derrick. PJSM. Load up shop, camp and pits and prepare to move from Drill Site 1 to Drill Site 2. Lower derrick and move Sub off well. -Move pits, camp and shops to Drill Site 2 Move Substructure from Drill Site 1 to Drill Site 2. Raise and Pin Derrick and Cattle Shute. Wait on ground prep around Well 02-28A. Lay mats around 02-28A. -Line up Sub, lay herculite, spot Sub and close cellar doors Spot pits, camp, shop, cuttings tank, and mud shack. -Berm up and bridle down. -Rig up floor and cellar. Accept Rig for Operations on 02-28A ~ 12:30 on 5/1/08 12:30 - 14:30 2.00 WHSUR P DECOMP PJSM Ria un DSM Lubricator and tPSt to 250 nsi for 5 min - good. 14:30 - 15:00 0.50 WHSUR P DECOMP Hold Pre-Spud Meeting in the Dog House. 15:00 - 16:00 1.00 WHSUR P DECOMP PJSM. Install secondary annulus valves. -Rig up to reverse diesel from tubing. -Test lines to 3500 psi. 16:00 - 17:00 1.00 WHSUR P DECOMP Reverse diesel from tubing ~ 180 gpm, 500 psi. -Swap circ lines and circulate diesel out from annulus. -Check for flow -well static. 17:00 - 18:00 1.00 WHSUR P DECOMP Perform in'ectivit test down IA. -Establish injection @ 20 gym, 1700 psi._ -Irijected 6 bbls into formation. 18:00 - 18:30 0.50 WHSUR P DECOMP Install BPV and test from below to 1000 si. -Pressure bleeding off down hole. -No pressure above BPV. 18:30 - 21:00 2.50 WHSUR P DECOMP PJSM. Nipple down tree and adapter flange. '~, -Remove from cellar. -Install blanking plug in BPV to convert to TWC. -Screw in XO to hanger to check threads -good. 21:00 - 23:30 2.50 BOPSU P DECOMP Nipple up adapter flange and BOP stack. -Install riser and turn buckles 23:30 - 00:00 0.50 BOPSU P DECOMP PU and rig up 3-1/2" test joint. 5/2/2008 00:00 - 01:00 1.00 BOPSU P DECOMP Continue to rig up testing equipment and lines for BOP test. 01:00 - 09:30 8.50 BOPSU P DECOMP Test BOPE. -Test Upper 3.5" x 6" VBR to 250 psi low / 3500 psi high with 3.5" and 5.5" test joint. -Test Annular Preventer with 3.5" test joint to 250 psi low / 2500 psi high. -Test Choke manifold and all BOPE related valves. -Test witnessed by AOGCC rep Lou Grimaldi and WSL Mark Staudinger. 09:30 - 10:30 1.00 BOPSU P DECOMP Blow down surface equipment. -Break down and lay down test joint. 10:30 - 12:30 2.00 BOPSU P DECOMP Pick u and ri u DSM _Tcet in 7Fn nci Printed: 6/10/2008 11:13:28 AM • BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 0 ell Name: 0 e: Name: From - To 2-28 2-28 WORKOVER NABORS ALASK NABORS 2ES Hours ~ Task i DRI Code Start LLING I Rig Rig N NPT Phase I Spud Date: 2/27/1990 : 4/28/2008 End: 5/15/2008 Release: 5/18/2008 umber: Description of Operations 5/2/2008 10:30 - 12:30 2.00 BOPSU P DECOMP - BPV ulled on third attem~, -Rig down lubricator. 12:30 - 13:00 0.50 PULL P DECOMP PJSM. Pick up casing running tools to floor up beaver slide. 13:00 - 15:30 2.50 PULL P DECOMP Attempt to screw into hanger. -Wash down to tubing hanger with top drive. -Screw into hanger (6 turns on 9" LH ACME) -Back out lock down screws -Pull han er free with 110k Ibs; Up Wt = 110k. -Lay down landing joint and hanger. 15:30 - 16:00 0.50 PULL P DECOMP Rig up 4-1/2" tubing equipment. -Rig up Camco Spooling Unit 16:00 - 19:00 3.00 PULL P DECOMP PJSM_Lay down 4-1/2" 12.6# L-80 BTC-M Tubina from 8888' to 6890'. -Spooling both control line and injection line with spooling unit. 19:00 - 21:00 2.00 PULL P DECOMP Well U-tubing. Pump dry job. Well still flowing up tubing. -Circulate clean 9.8 ppg brine around ~ 6.5 bpm, 950 psi. -Saw Maraseal Squeeze Gel (hi-vis polymer) over shakers. -Pump another dry job - no flow. 21:00 - 22:00 1.00 PULL P DECOMP Lay down 4-1/2" tubing from 6890' to 5780'. -Recovered 75 joints of 4-1/2" tubing and (75) 4-1/2" clamps. 22:00 - 22:30 0.50 PULL P DECOMP Change out handling equipment to 3-1/2". 22:30 - 00:00 1.50 PULL P DECOMP Lay down 3-1/2" 9.3# L-80 EUE 8RD Tubing from 5780' to 4225'. -Continue spooling injection line with spooling unit. 5/3/2008 00:00 - 12:00 12.00 PULL P DECOMP Continue pulling 3-1/2" Tubing with injection line from 4225'. -Recovered 182 full jts of 3-1/2" tubing, (181) 3-1/2" clamps (2 were missing 1 pin), 18 S.S. Bands, 7 GLM's, 1 Chemical Injection Mandrel. -3-1/2" Cut jt indicated good cut and strapped ~ 12.75'. -Lay down spooling unit, power tongs, and clear floor. 12:00 - 12:30 0.50 PULL P DECOMP Lay down tubing equipment and change out elevators. 12:30 - 13:30 1.00 BOPSU P DECOMP Rig up 3-1/2" test joint and test lower VBR to 250 psi low / 350 -Pull test plug and install wear ring. 13:30 - 14:30 1.00 CLEAN P DECOMP Pick up 3.5" Stub Dress-off BHA to rig floor. 14:30 - 15:30 1.00 CLEAN P DECOMP Make up BHA and change out handling equipment. 15:30 - 22:30 7.00 CLEAN P DECOMP Pick up 4" DP from 220' to 8810'. -Install blower hose. 22:30 - 23:30 1.00 CLEAN P DECOMP Circulate high vis sweep around ~ 10 bpm, 2450 psi. -Very little Maraseal Squeeze Gel seen in sweep. 23:30 - 00:00 0.50 CLEAN P DECOMP Establish parameters - 4 bpm C~ 400 psi. -Up Wt = 160k, Dn Wt = 150k -65 rpm with 4k ft-Ibs free TO. -Dress outside of tubing stub and rotate down to 8898'. -Begin dressing off tubing stub with inner mill with 2k WOB and 5.5k ft-Ibs TO. *Lossin < 1 bbl/hr Gtat~~ a~~ ~„n~,.,~~t 5/4/2008 00:00 - 02:00 2.00 CLEAN P DECOMP Continue dressing 3-1/2" tubing stub. -4 bpm C~ 400 psi. -65 rpm with 4200 ft-Ibs Free TO. -Attempt to dress stub with I.D. mill, but appeared to have junk Nnrnea: oiiuizuua 77:1 J:"Ltl HM • BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: 02-28 Common Well Name: 02-28 Spud Date: 2/27/1990 Event Name: WORKOVER Start: 4/28/2008 End: 5/15/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/18/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/4/2008 00:00 - 02:00 2.00 CLEAN P DECOMP on outside. 02:00 - 03:00 1.001 CLEAN ~ P 03:00 - 04:30 1.50 CLEAN P 04:30 - 07:30 3.00 CLEAN P 07:30 - 08:30 1.00 CLEAN N 08:30 - 10:00 1.50 CLEAN P 10:00 - 12:00 2.00 CLEAN P 12:00 - 13:00 I 1.001 CLEAN I P 13:00 - 14:00 1.00 CLEAN P 14:00 - 16:00 2.00 CLEAN P 16:00 - 17:30 1.50 CLEAN P -Topdrive stalling out, took 40k overpull and came free. -Junk appeared to have fallen down. -Dress I.D. of stub and mill to 8887.5' DECOMP Pump hi-vis sweep around ~ 425 gpm, 2400 psi. -Sweep was clean. DECOMP Slip and cut 85' of drilling line. DECOMP POH, laying down Drill Pipe from 8899' to 5540'. RREP DECOMP Replace cracked hydraulic hard line on iron roughneck. DECOMP Continued to lay down drill pipe from 5540' to 3958'. DECOMP POH, racking back stands from 3958' to 220'. -Work 7-5/8" scraper from 3779' to 3653'. DECOMP Lay down Stub Dressing BHA. -Recovered -1 gallon of metal shavings from boot baskets. DECOMP Clean and clear rig floor. DECOMP " RTTS and RIH to 3835'. DECOMP Break circulation C~ 2 bpm, 60 psi and wash setting area. - i est casino above n i i a to ~ovv usi wi ov n m i - yu~u. -Release RTTS 17:30 - 18:30 1.00 CLEAN P DECOMP POH from 3827' to 190'. 18:30 - 19:30 1.00 CLEAN P DECOMP Lay down RTTS and clear rig floor. 19:30 - 21:00 1.50 CASE P DECOMP Ri u to run 5-1/2" Scab Liner. 21:00 - 22:00 1.00 CASE P DECOMP PJSM. Make up 3-1/2" Unique Overshot, Ported XO, and 5-1/2" Float Equipment. -Dropped ball onto Type II Landing Collar and placed 1 bag of sand (-10 feet) of sand above. -Checked float collar -good. 22:00 - 00:00 2.00 CASE P 5/5/2008 00:00 - 04:00 4.00 CASE P 04:00 - 04:30 0.50 CASE P 04:30 - 07:30 3.00 CASE P 07:30 - 08:30 I 1.00 I CASE I P 08:30 - 09:30 I 1.001 CASE f P 09:30 - 12:00 I 2.501 CASE I P DECOMP Run 5-1/2" 15.5# L-80 BTC-M Scab Liner to 1625'.., -Ave TO = 5200 ft-Ibs. DECOMP Continue to RIH with 5-1/2" 15.5# L-80 BTC-M Scab Liner to 5156'. -Make up Baker liner hanger and running tool. DECOMP Break circulation and circ liner volume ~ 270 gpm, 440 psi. DECOMP Run 5-1/2" liner in hole on DP to 8874' -Lay down single. DECOMP Make up cement head to single joint of pipe. -Rig up cementing lines. -Make up cement head and single to string and fill drill pipe. -Up wt 157k, down wt. 139k -RIH and to shear scr -Ta u on n -Pick up and confirm no go w/17k slack off. -Pick up to string weight + 2' to 8890.7' -Overshot swallowing stub by 6' DECOMP Circulate 3 BPM ~ 265 psi -Hold pre-job safety meeting with crews and cementers. DECOMP Rig up cement lines to SLB cementing unit and pump 5 bbls water. -Pressure test lines to 4500 psi. -Pump 27.7 bbls 11.0 ppg mud push II with red dye -Pump 56.4 bbl 11 Lite Crete ~ 5 BPM / 1075 psi - ump 53.8 bbl 15.8 ppg class G Tail slurry at 3 BPM ~ 700 Printed: 6/10/2008 11:13:28 AM • BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: 02-28 Common Well Name: 02-28 Spud Date: 2/27/1990 Event Name: WORKOVER Start: 4/28/2008 End: 5/15/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/18/2008 Rig Name: NABOBS 2ES Rig Number: Date 'From - To Hours Task I Code NPT Phase -- _ 5/5/2008 109:30 - 12:00 2.50 CASE P Description of Operations DECOMP psi -Wash up cement lines through Tee -Switch to rig pump, drop wiper dart -tattle tale confirmed dart left head. -Displace with rig pumps, chase cement at 5 BPM 200 psi. -Latch u to liner wiper lu ~ 527 stks -Bump plug C~ 2620 stks pressure up to 2800 psi. -Slack off 40k Ibs to set hanger. -Press unto 4000 psi to set LTP. Bleed off & check floats - -Pressure up to 4300 psi. Bleed off. -Rotate 15 turns to right to release running tool. -Pressure up to 1000 psi and pick up 6' until pressure drops. -Pump cement up hole at 540 GPM ~ 2770 psi for 600 stks. -Slow pump to 2 BPM and slack off 50k to confirm set - ok. Pick up. -Rotate and slack off 50k; repeat. -Pick up 10' and pump cement out of hole at 544 GPM C~ 2500 psi. -15 11:30 - 13:00 1.50 CASE P 13:00 - 14:30 1.50 CASE P 14:30 - 15:30 1.00 CASE P 15:30 - 16:30 1.00 WHSUR P 16:30 - 18:30 2.00 WHSUR P 18:30 - 21:00 2.50 BOPSU P 21:00 - 22:00 1.00 CLEAN P 22:00 - 00:00 2.00 CLEAN P 5/6/2008 00:00 - 07:30 7.50 CLEAN P 07:30 - 09:00 1.50 CLEAN P 09:00 - 10:30 I 1.50 I CLEAN I P 10:30 - 11:30 11:30 - 12:00 1.00 CLEAN P 0.50 CLEAN P 12:00 - 14:00 14:00 - 17:00 17:00 - 23:00 DECOMP Blow down all circ lines. Rig down cement head and lines. DECOMP POH from 3735' and lay down liner running tool. DECOMP Pull wear ring and function BOP stack. -Jet BOP's and blow down top drive. DECOMP Pull existing 7-5/8" packoff through BOP stack. Change out with new packoff. DECOMP Test packoff to 5000 psi for 30 minutes. DECOMP Install test plug and Make up 2-7/8" Tesi Joint. -Test lower VBR to 250 psi low / 3500 psi high. -Test annular to 250 psi low / 2500 psi high. -Rig down test equipment, pull test plug, and install wear ring. DECOMP Rig up Power Tongs and 2-7/8" handling equipment. DECOMP Make u t A to 193'. DECOMP RIH with drill out assembly picking up 2-7/8" PAC pipe to 5201'. DECOMP RIH to 8657'. Hook up blower hose. Break circulation. Up weight 130k, down 110k, RT 120k. DECOMP Wash and ream to 8695' at 150 gpm with 1825 psi. Rotate at 15 rpm with 2k free torque. Tag cement at 8695'. Drill up plug and landing collar to 8745'. WOB 2-4k. Torque 2-3k. DECOMP Circulate BU at 155 gpm with 2025 psi. DECOMP Shut upper rams and test casino to 3500 osi for 30 minutes - 2.00 CLEAN P DECOMP Drill cement and float equipment to 8856'. Pump at 150 gpm with 1900 psi off bottom, 2050 psi on bottom. WOB 3-4k. Rotate. at 15 rpm with 2-3k torque. Up weight 130k, down 110k, RT 120k. 3.00 CLEAN P DECOMP Circulate hi-vis sweep S-S at 155 gpm with 2030 psi. Rotate and reciprocate. Pump second hi-vis sweep at 160 gpm with 2120 psi. Mud weight in and out 9.8 ppg. 6.00 CLEAN P DECOMP POOH with 2-7/8" PAC and 4" drill pipe to drill out assembly at Printed: 6/10/2008 11:13:28 AM r~ • BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: 02-28 Common Well Name: 02-28 Spud Date: 2/27/1990 Event Name: WORKOVER Start: 4/28/2008 End: 5/15/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/18/2008 Rig Name: NABORS 2ES Rig Number: Date From - To ', Hours Task Code NPT Phase Description of Operations 5/6/2008 17:00 - 23:00 6.00 CLEAN P DECOMP 193'. 23:00 - 00:00 1.00 CLEAN P DECOMP POOH laying down drill out assembly. 5/7/2008 00:00 - 01:00 1.00 CLEAN P DECOMP POOH laying down 2-7/8" cleanout assembly. 01:00 - 02:00 1.00 CLEAN P DECOMP PU and RIH with 2-1/16" cleanout assembl to 198'. 02:00 - 04:00 2.00 CLEAN N WAIT DECOMP Waiting on third party tools. The 2-1/16" x 2-7/8" XO split on box end and the 2-7/8" PAC pin end was belled. 04:00 - 09:00 5.00 CLEAN N WAIT DECOMP RIH with 2-1/16" cleanout assembly to 8788'. Up weight 130k, down 110k. 09:00 - 18:30 9.50 CLEAN N WAIT DECOMP RIH and to u at 8858'. Pump at 70 gpm with 1045 psi off bottom, 1200 psi on bottom. WOB 1-2k. Drill up cement stringers, ball and ball seat. Wash down pushing funk ahead to obstruction at 8971', tag up. Try to mill ahead with no success. 18:30 - 21:00 2.50 CLEAN N WAIT DECOMP Pump out of 3-1/2" tubing to 8850' at 70 gpm with 1140 psi. Restriction and pack off at 8870'. Run back in and tag ua again at 8971'. Pump back out to 8850'. Drop ball and open circ sub. Circulate hi-vis sweep S-S at 240 gpm with 3700 psi. Mud weight in and out 9:8 ppg. No sluggits to surface and no metal. Pump dry job. Blow down top drive. 21:00 - 00:00 3.00 CLEAN N HMAN DECOMP POOH to 2797'. 5/8/2008 00:00 - 02:30 2.50 CLEAN N HMAN DECOMP PJSM. POOH with 2-1/16" cleanout assembly to 16'. 02:30 - 03:00 0.50 CLEAN N HMAN DECOMP Lay down milling assembly. 03:00 - 04:00 1.00 CLEAN N HMAN DECOMP PJSM. PU and MU RCJB assembly to 30'. 04:00 - 09:30 5.50 CLEAN N HMAN DECOMP RIH with RCJB on 2-7/8" PAC drill i to 8803'. Up weight 130k, down 110k. 09:30 - 18:00 8.50 CLEAN N HMAN DECOMP Wash down to 8970'. Pump at 70 gpm with 1920 psi. WOB 1-2k. Progress slow with motor stalling out. Attempt to feather and lightly spud while milling and washing. Motor continues to stall out. Mill and wash to 8972'. Pump out to 8850'. 18:00 - 19:30 1.50 CLEAN N HMAN DECOMP Drop ball and open circ sub. Circulate hi-vis sweep S-S at 240 gpm with 3750 psi. No sluggits to surface. Mud weight in and out 9.8 ppg. Pump dry job. Blow down top drive. 19:30 - 23:30 4.00 CLEAN N HMAN DECOMP PJSM. POOH to 214'. 23:30 - 00:00 0.50 CLEAN N HMAN DECOMP PJSM. POOH and lay down RCJB assembly. 5/9/2008 00:00 - 00:30 0.50 CLEAN N HMAN DECOMP PJSM. Break and lay down RCJB. Recover misc iron, brass, aluminum, SS and sluggits. Recovered 1 gallon from lower section. Upper basket still full, quantity will be determined when dumped at Baker shop. 00:30 - 09:00 8.50 BOPSU N HMAN DECOMP PJSM. Test BOP 50 psi low, 3500 psi high and hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Bob Noble with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Bruce Simonson. 09:00 - 09:30 0.50 BOPSU N HMAN DECOMP Rig down testing equipment. Run in wear ring. Blow down. 09:30 - 10:00 0.50 CLEAN N HMAN DECOMP PJSM. PU and RIH with RCJB to 203'. 10:00 - 17:00 7.00 CLEAN N HMAN DECOMP RIH to 8793'. Up weight 130k, down 110k. 17:00 - 18:00 1.00 CLEAN N HMAN DECOMP Wash and work to 8972'. Pump at 110 gpm with 4100 psi. WOB 2k. 18:00 - 19:00 1.00 CLEAN N HMAN DECOMP Pump hi-vis sweep at 115 gpm with 4100 psi. Drop ball, open circ sub. Increase pump rate to 240 gpm with 3900 psi. No material to surface. 19:00 - 23:30 4.50 CLEAN N HMAN DECOMP POOH to 203'. 23:30 - 00:00 0.50 CLEAN N HMAN DECOMP PJSM. Lay down 2-1/16" pipe. Break RCJB and empty barrel. Recovered a handful of brass, iron, aluminum and 2 pieces of SS banding. Printed: 6/10/2008 11:13:28 AM • • BP EXPLORATION Operations Summary Report Page 6 of 10 Legal Well Name: 02-28 Common Well Name: 02-28 Spud Date: 2/27/1990 Event Name: WORKOVER Start: 4/28/2008 End: 5/15/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/18/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours I Task I, Code NPT Phase ', Description of Operations 5/10/2008 00:00 - 01:30 1.50 CLEAN N HMAN DECOMP PJSM. Lay down RCJB assembly. Clear and clean floor. 01:30 - 02:30 1.00 CLEAN N HMAN DECOMP PJSM. PU and MU RCJB and mill assembly. 02:30 - 07:00 4.50 CLEAN N HMAN DECOMP RIH with mill and RCJB run #3 to 8895'. 07:00 - 11:00 4.00 CLEAN N HMAN DECOMP Establish circulation at 73 gpm with 1660 psi. Up weight 130k, down 112k. Wash down to 8972'. WOB 1-2k. Motor stalling out. Work several times. No further headway made. Rack back one stand. Drop ball, open circ sub. Pump dry job. Mud weight in and out 9.8 ppg. 11:00 - 15:00 4.00 CLEAN N HMAN DECOMP PJSM. POOH with RCJB assembly to 212'. 15:00 - 16:00 1.00 CLEAN N HMAN DECOMP PJSM. POOH with RCJB BHA. Break and clean out RCJB. Recovered a considerable amount of metal and sluggits. Clear 16:00 - 16:30 0.50 CLEAN N HMAN DECOMP Change out circ sub and disconnect. RIH with RCJB BHA to 212'. 16:30 - 21:30 5.00 CLEAN N HMAN DECOMP RIH with RCJB assembly #4 to 8894'. Fill pipe. 21:30 - 00:00 2.50 CLEAN N HMAN DECOMP Wash down and tag at 8972.3'. Wash and mill Venturi at 70 gpm with 1875 psi off bottom, 2300 psi on bottom. WOB 2k. Stall several times then able to make stead headwa to 8973.7'. Work stand back up, break off and drop circ sub opening ball. 5/11/2008 00:00 - 02:30 2.50 CLEAN N HMAN DECOMP PJSM. Open up circ sub. Pump hi-vis spacer followed by seawater. Displace well to seawater. 02:30 - 05:30 3.00 CLEAN N HMAN DECOMP POOH with RCJB assembly to 212'. 05:30 - 06:30 1.00 CLEAN N HMAN DECOMP POOH wtih BHA. Break out RCJB and motor. Recover hand full of small metal shavin sand debris. Clear and clean floor. 06:30 - 07:30 1.00 DHB N HMAN DECOMP PJSM. Make up retrieval tool BHA to 13'. 07:30 - 12:00 4.50 DHB N HMAN DECOMP RIH to 8880'. 12:00 - 15:00 3.00 DHB N HMAN DECOMP Fill drill pipe. Up weight 130k, down 110k. Circulate at 42 gpm with 1350 psi. Wash down and tag 3-1/2" tubing top at 8887'. PU work in 2 turns pass through tubing top. Tag bottom at 8973'. Set 5k down on fish with no pressure increase. Shut down pumps, pick up to 8955' with no overpull. Monitor well, no change. Repeat process with pumps off and pumps on at 142 gpm with 4150 psi. Rotate pipe and repeat. No change in hole conditions. Drop ball, open circ sub and pump dry job. 15:00 - 19:00 4.00 DHB N HMAN DECOMP POOH to BHA. 19:00 - 20:00 1.00 DHB N HMAN DECOMP PJSM. Lay down spear, circ sub, jar, check valve and disconnect. 20:00 - 21:00 1.00 CLEAN N HMAN DECOMP PU mule shoe, 5 joints 2-1/16", XO's and boot baskets to 169'. 21:00 - 00:00 3.00 CLEAN N HMAN DECOMP RIH to 7139'. 5/12/2008 00:00 - 01:00 1.00 CLEAN N HMAN DECOMP PJSM. RIH to 8915'. Make up top drive. Fill pipe and establish circulation at 200 gpm with 2475 psi. Up weight 130k, down 110k. Run in and tag up at 8973' with 5k down. Work up and down several times with no gain. Increase pump rate to 260 gpm with 3850 psi. Work several times with no footage pained. 01:00 - 02:00 1.00 CLEAN N HMAN DECOMP Circulate sweep S-S at 270 gpm with 3850 psi. Re ovPrPd small amount of scale and debris in retur s. Pump dry job. 02:00 - 06:00 4.00 CLEAN N HMAN DECOMP PJSM. POOH laying own drill pipe to 5270'. 06:00 - 07:00 1.00 CLEAN N HMAN DECOMP PJSM. Cut and slip 114' of drilling line. 07:00 - 08:00 1.00 CLEAN N HMAN DECOMP PJSM. Service top drive, crown and draworks. Inspect draworks. Adjust brakes. 08:00 - 12:00 4.00 CLEAN N HMAN DECOMP PJSM. Load pipe shed. Strap and prep drill pipe. PUr 4" drill pipe to 7977', Printed: 6/10/2008 11:13:28 AM • • BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 02-28 02-28 Spud Date: 2/27/1990 WORKOVER Start: 4/28/2008 End: 5/15/2008 NABOBS ALASKA DRILLING I Rig Release: 5/18/2008 NABOBS 2ES Rig Number: Date i From - To ; Hours I Task 'Code 5/12/2008 12:00 - 15:30 3.50 CLEAN N 15:30 - 16:30 1.00 CLEAN N 16:30 - 20:00 20:00 - 22:00 22:00 - 00:00 5/13/2008 00:00 - 01:30 01:30 - 02:45 02:45 - 03:30 03:30 - 06:00 06:00 - 08:30 08:30 - 11:00 11:00 - 11:30 11:30 - 15:00 15:00 - 16:30 16:30 - 18:30 18:30 - 19:00 19:00 - 23:30 23:30 - 00:00 5/14/2008 100:00 - 00:30 00:30 - 03:45 3.501 EVAL I N 2.00 EVAL N 2.00 EVAL N 1.50 EVAL N 1.25 EVAL N NPT Phase ~', Description of Operations HMAN DECOMP PJSM. POOH to 162'. HMAN DECOMP Break and lay down XO's and boot baskets. Recover 3 pieces of iron sand and scale. Lay down 2-1/16" CS Hydril pipe. Clear and clean floor. HMAN DECOMP PJSM. PU slickline tools and equipment. Install lubricator extension in BOP stack, MU pump in sub and SWS BOP unit. Dress top shiv packoff unit and make up tool head to wire. Tie onto upper lubricator through top drive bales. MU and hoist. Align and secure floor shiv. MU final tool assembly. Stab and test lubricator to 500 psi - OK. HMAN DECOMP RIH with 2-3/4" flat bottom impression block. Ta at 8992' WLM. POOH. Some side wear on tool with impression of rounded edge on outermost of block. HMAN DECOMP RIH with 2-3/4" to ered im ression block. Ta u at 8992', WLM. POOH, HMAN DECOMP Rig down impression block running tool. Impressions on bottom of tapered block appear to be from internal screen on CAT valve. No impression on cone section of impression block. Round up tools for next run. HMAN DECOMP RIH with 2.25 tapered impression block. Tag up at 8992' WLM. 0.75 EVAL N HMAN DECOMP Rig down impression block running tool. Impression of inner screen on end of tapered block. Small indication of lower most profile at 2.21" ID which is 1"off screen. 2.50 EVAL N HMAN DECOMP Rig down slickline unit. Prepare to run in hole with drill pipe and lay down same. 2.50 EVAL N HMAN DECOMP RIH to 7811'. 2.50 EVAL N HMAN DECOMP Perform rig maintenance while waiting on orders from town. 0.50 CLEAN N HMAN DECOMP Establish circulation. Pump dry job at 130 gpm with 923 psi. 3.50 CLEAN N HMAN DECOMP POOH. Clear derrick of ice build up. 1.50 CLEAN N HMAN DECOMP Service rig, top drive and drawworks. 2.00 CLEAN N HMAN DECOMP PJSM. PU 4" drill pipe and stand back. 0.50 CLEAN N HMAN DECOMP PJSM. PU and MU stepped pilot mill assembly to ~~5'ti 4.50 CLEAN N HMAN DECOMP RIH to 8918'. Make up top drive. Fill pipe, wash and tag at 8973'. 0.50 CLEAN N HMAN DECOMP Circulate at 70 gpm with 950 psi. Establish off bottom slow pump rate at 42 gpm with 366 psi. Ran hark to nnttnm and st rted millin on CAT valy . WOB 1-1.5k. Up weight 130k, down 115k. 0.50 CLEAN N HMAN DECOMP PJSM. Continue to mill ahead. Pumping at 70 gpm with 950 psi. WOB 1-1.5k. Appear to be milling on string mill. Milled 6". 3.25 CLEAN N HMAN DECOMP Increase in flow noted with no increase in pit volume. Monitor and continue to mill. Flow continued to increase. Pull up off bottom. Position tool joint. Shut down um s. Well flowin . Shut in Hvdril at 00:44 hours. nnounced well control incident. All hands responded to proper stations. Shut in manifold valve down stream from choke. Monitor well on choke panel. Casing pressure at 40 psi. Drill pipe pressure at 0 psi. Had a 17 bbl gain. Notify day WSL Blair Neufeld and day Toolpusher Cleve Coyne. Blair notified AOGCC rep Jeff Jones state and BP town personnel. Held huddle up with rig crew. Talked over situation and outlined Printed: 6/10/zoos t1:13:2a AM • BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: 02-28 Common Well Name: 02-28 Spud Date: 2/27/1990 Event Name: WORKOVER Start: 4/28/2008 End: 5/15/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/18/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/14/2008 00:30 - 03:45 3.25 CLEAN N HMAN DECOMP plan forward. Opened up lines to gas buster and lined up to circulate out gas. It was decided not to weight up but to circulate out gas. Mud weight in and out 8.5 ppg. Started circulation at 01:10 hours. Pump at 29 spm, 71 gpm DP pressure at 920 psi, CA pressure at 170 psi. 03:45 - 04:15 0.50 CLEAN N HMAN DECOMP 04:15 - 09:30 5.25 CLEAN N HMAN DECOMP 09:30 - 14:30 5.00 CLEAN N HMAN DECOMP 14:30 - 15:00 0.50 CLEAN N HMAN DECOMP 15:00 - 16:30 1.50 BOPSU N HMAN DECOMP 16:30 - 20:00 3.50 FISH N HMAN DECOMP 20:00 - 22:00 2.00 FISH N HMAN DECOMP 22:00 - 00:00 2.00 FISH N HMAN DECOMP 5/15/2008 00:00 - 02:30 2.50 FISH N HMAN DECOMP 02:30 - 03:30 1.00 FISH N HMAN DECOMP 03:30 - 06:00 2.50 FISH N HMAN DECOMP 06:00 - 08:00 2.00 FISH N HMAN DECOMP Time DP CA MW in/out 01:20 910 70 8.5/8.5 01:30 890 50 01:40 900 40 01:50 910 40 8.5/8.5 02:00 900 20 02:50 900 10 03:20 900 10 8.5/8.5 Shut down pumps at 03:28 hours at 4000 strokes. Close choke. Monitor pressures. No pressure on DP or CA. Open choke and bleeder. Clear floor and open Hydril. Fluid dropped in stack. Fill stack and monitor well for 10 minutes. No flow. Pull up 3 stands and monitor well for losses. Well static. Run stands back in hole. Up weight 130k, down 115k. Continue milling operations. Pumping at 69 gpm with 1025 psi. WOB 1-1.5k. No losses or gains. With mill on bottom, 10-80 psi differential. Slack off, motor working good. Mill on screen. Make another 6-7". Shut down. PJSM. Drop ball, open circ sub. Pump dry job. POOH to 175'. PJSM. Lay down XO's , 5 joints CS Hydril, mill and motor. PJSM. Rig up and test Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Jeff Jones with AOGCC. Test witnessed by WSL Blair Neufeld and Toolpusher Cleve Coyne. PJSM. PU and MU Slickline equipment. Make up string tools. Stab 2.25 tapered impression block (TIB). Test lubricator assembly to 500 psi - OK. RIH and tag TIB at 8892'. POOH Break off and evaluate. PU and MU 1.583" grapple. Stab in lubricator and test to 500 psi - OK. RIH and tag bottom at 8992'. Jar and work down several times. One slight overpull then release. Work several more times with no success. POOH. Evaluate. MU 2.75 TIB. Stab and test to 500 psi - OK. PJSM. RIH with 2.75" TIB and tag bottom at 8992'. POOH. Evaluate TIB. PU and stab bailer. Test lubricator to 500 psi - OK. RIH with bailer and work on bottom. POOH. Recover small amount of metal shavings. PU and stab spear with 1.556" grapple. Test lubricator to 500 psi - OK. RIH with 1.556" grapple. Work and jar down several times no indication of latch up. POOH. Tight spot at 8866'. Grabing tool then releasing. Retrieved tool. Nose scarred up but no wear on the grapple. Pick up and MU a taddle tail prong. Stab taddle tail prong. Test to 500 psi - OK. RIH to 8973', POOH. Prong showed we were not able to penetrate below Printed: 6/10/2008 11:13:28 AM • BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: 02-28 Common Well Name: 02-28 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES i Date ~ From - To Hours- Task ,Code NPT Spud Date: 2/27/1990 Start: 4/28/2008 End: 5/15/2008 Rig Release: 5/18/2008 Rig Number: Phase Description of Operations 5/15/2008 06:00 - 08:00 08:00 - 10:00 10:00 - 13:30 2.00 2.00 3.50 FISH FISH FISH N N N HMAN HMAN HMAN DECOMP DECOMP DECOMP screen. Perform regular maintenance while waiting on tools to be made up for next run. Make up tapered tap. Stab in lubricator. Test to 500 psi - OK. RIH and att m t to rec ver lu .Start to loose fluid. POOH to surface. No fish. Fill hole over top and regain surface flow. Lost 33 bbls overall. Stab same taper tap into lubricator. Test to 500 psi - OK. 13:30 - 16:00 2.50 FISH N HMAN DECOMP RIH with taper tap. Jar down several times. Unable to stay engaged. POOH. No losses. Pick up spring loaded slip spear. Stab into lubricator. Test to 500 psi - OK. 16:00 - 17:30 1.50 FISH N HMAN DECOMP RIH and tag up. Spud in and jar on fish. Again, unable to stay engaged. POOH. No fish. Well static, no losses. 17:30 - 19:00 1.50 FISH N HMAN DECOMP PJSM. Rig down Slickline unit and equipment. Well static. 19:00 - 20:00 1.00 CLEAN N HMAN DECOMP PJSM. PU and MU pilot mill BHA to 175'. Upper mill turned down to 2.3". 20:00 - 00:00 4.00 CLEAN N HMAN DECOMP RIH with pilot mill assembly to 7609'. 5/16/2008 00:00 - 01:00 1.00 CLEAN N HMAN DECOMP PJSM. RIH to 8918'. Make up top drive. Up weight 133k, down weight 115k. Pump at 71 gpm with 990 psi on bottom, 900 psi off bottom. 01:00 - 07:30 6.50 CLEAN N HMAN DECOMP Tag up at 8972.7'. Work up and mill through several times on upper mill. Motor stalling out several times, then make head 07:30 - 08:30 I 1.00 I CLEAN I N 08:30 - 17:00 8.50 CLEAN N 17:00 - 18:00 1.00 CLEAN N 18:00 - 18:30 0.50 CLEAN N 18:30 - 19:30 1.00 BOPSU N 19:30 - 00:00 I 4.501 BOPSUR N 5/17/2008 100:00 - 02:00 02:00 - 05:30 05:30 - 06:00 06:00 - 09:30 09:30 - 11:00 11:00 - 12:30 12:30 - 13:00 13:00 - 15:00 2.001 BOPSUFIN 3.50 FISH N 0.50 FISH N 3.50 FISH N 1.50 FISH N 1.50 FISH N 0.50 BUNCO 2.00 BUNCO HMAN ~ DECOMP~ rop ball, open circ sub. Circulate out. Pump dry job. Mud weight in and out 8.5 ppg. HMAN DECOMP PJSM. Trip out of hole laying down drill pipe to 175'. HMAN DECOMP PJSM. Lay down milling BHA. Clear and clean floor. HMAN DECOMP PJSM. Lay handling equipment down beaver slide. HMAN DECOMP Grease choke manifold. PU test joint. Remove wear ring. Run in test plug. Fill stack and choke. Test for leaks - OK. HMAN DECOMP PJSM. Test BOPE to 250 i hi hand Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher John Castle. Test 3-1/2" and 4-1/2" test joints. HMAN DECOMP PJSM. Test BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher John Castle. Test 3-1/2" and 4-1/2" test joints. HMAN DECOMP PJSM. Rig up Slickline lubricator and equipment. HMAN DECOMP PJSM. Stab 1.583" grapple. Test lubricator to 500 psi - OK. RIH. HMAN DECOMP PJSM. RIH with grapple and spear into CAT vai~~o I Inahlo r~ ull free. Release from grapple. POOH. MU down release tool. Stab in lubricator. Test to 500 psi - OK. RIH and engage grapple. Pull and release CAT valve. POOH and retrieve CAT valve. We I static. HMAN DECOMP Lay down CAT valve. Make up 4.60" gauge ring. RIH to 8867' WLM. POOH. HMAN DECOMP PJSM. Rig down Slickline tools. Rig down unit. RUNCMP Run in test joint with running tool and pull wear ring. RUNCMP PJSM. Rig up to run casing. Change out bales. Rig up double Printed: 6/10/2008 11:13:28 AM A BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: 02-28 Common Well Name: 02-28 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date From - To I~, Hours Task !~ Code NPT Spud Date: 2/27/1990 Start: 4/28/2008 End: 5/15/2008 Rig Release: 5/18/2008 Rig Number: Phase Description of Operations 5/17/2008 13:00 - 15:00 2.00 RU 15:00 - 00:00 9.00 RU RUNCMP stack casing tongs and computers. RUNCMP PJSM. Run 3-1/2" x 4-1/2", 9.2#/12.6#, 13Cr-80, Vam 5/18/2008 00:00 - 05:00 5.00 BUNCO RUNCMP PJSM. Run 3-1/2" x 4-1/2", 9.2#/12.6#, 13Cr-80, Vam Top completion tubing to 8858'. Space out, make up pup at 5.81 ". Make up hanger. Rig down casing running equipment. PUW 105, SOW 93k. 05:00 - 06:00 1.00 BUNCO RUNCMP Land hanger in profile. Rig up to circulate and pump corrosion inhibitor. Run in lock down screws. 06:00 - 08:00 2.00 BUNCO RUNCMP PJSM. Circulate and displace annulus with inhibited seawater at 84 gpm with 200 psi. 08:00 - 09:30 1.50 BUNCO RUNCMP PJSM. Drop ball and rod ~eLnarkar wffh a5oo si fg_or 10~ si for 30 minutes - OK. Bleed off annulus then tubing. Pressure up on annulus and shear DCR valve with 2500 psi. Pump both ways to confirm shear. 09:30 - 10:00 0.50 BOPSU P RUNCMP PJSM. Set TWC. Test from above and below to 1000 psi - OK. 10:00 - 13:00 3.00 BOPSU P RUNCMP PJSM. Nipple down BOP stack and equipment. 13:00 - 15:30 2.50 WHSUR P RUNCMP PJSM. Bring adapter and tree into cellar. Make up adapter. Test void to 5000 psi for 30 minutes - OK. PU tree and NU. Test tree to 5000 psi - OK. Rig down test equipment. 15:30 - 16:30 1.00 WHSUR P RUNCMP PJSM. Pick up and make up DSM lubricator and test to 500 psi - OK. Pull TWC. Spot LRS for freeze protect. 16:30 - 20:00 3.50 WHSUR P RUNCMP PJSM. Hook up LRS. Pressure test lines to 3000 psi - OK. Pump 95 bbls diesel freeze protect down annulus. Take returns into cuttings box. Line up and U-Tube. 20:00 - 20:30 0.50 WHSUR P RUNCMP PJSM. Run in BPV. Test from below to 1000 psi - OK. Rig down LRS unit and equipment. 20:30 - 22:30 2.00 WHSUR P RUNCMP PJSM. Remove secondary annulus valve. Install gauges and needle valves on tree. DSM installed VR plug in IA. Secure tree. 22:30 - 00:00 1.50 RIGD P RUNCMP PJSM. Rig down floor. Blow down steam and water lines. Disconnect out buildings and cuttings box. Prep for move. Rig released at midnight. Printed: 6/10/2008 11:13:28 AM YY fill VVlll.l V1 V V Nlll VL-LV.~1 Regg, James B (DOA) From: Jones, Jeffery B {DOA) ~~~ ~I'~I~ Sent: Wednesday, May 14, 2008 2:22 PM To: DOA AOGCC Prudhoe Bay Subject: FW: Well control event 02-28A Attachments: Well Control Event 5-14-2008.doc From: Neufeld, Blair (ASRC) [mailto:Blair.Neufeld@bp.com] Sent: Wednesday, May 14, 2008 12:02 PM To: Jones, Jeffery B (DOA) Subject: Well control event 02-28A Jeff, Let me know if you need additional information. Blair Neufeld «Well Control Event 5-14-2008.doc» 1 U~\+ 1 V 1 1 MAY ~ ~ 200 5/15/2008 ~` Jeff , '~ Operations were milling on Standing valve which is set in the well at 8983' Fluid in the hole is seawater. Production section Max anticipated BHP 3300 psi (7.2 ppg EMW) @ 8800' TVD 00:32 Increase in flow noted with no increase in pit volume. Monitor and continue to mill. Flow continued to increase. 00:38 Pull up off bottom. Position tool joint. Shut down pumps. Well flowing. Shut in Hydril at 00:44 hours. Announced well control incident. All hands responded to proper stations. Monitor well on choke panel. Casing pressure at 40 psi. Drill pipe pressure at 0 psi. 17 bbl pit gain. Held huddle up with rig crew. Talked over situation and outlined plan forward. Opened up lines to gas buster and lined up to circulate out gas. It was decided not to weight up but to circulate out gas. Mud weight in and out 8.S ppg. Started circulation at 0110 hours. Pump at 29 spm, 71 gpm. DP pressure at 920 psi, CA pressure at 170 psi. Time DP CA MW in/out 0120 910 70 8.S/8.S 0130 890 SO 0140 900 40 O1S0 910 40 8.S/8.5 0200 900 20 0250 900 10 0320 900 10 8.S/8.S Shut down pumps at 0328 hours at 4000 strokes. Close choke. Monitor pressures. No pressure on DP or CA. Open choke and bleeder. Clear floor and open Hydril. Fluid dropped in stack. Fill stack and monitor well for 10 minutes. No flow. Start fluid amount 472 bbl Total after influx 489 bbl. Total at end of circulating 460 bbl. ,> Regg, James B (DOA) From: Jones, Jeffery B (DOA) / ~ IjSI~ Sent: Wednesday, May 14, 2008 3:39 AM JAS ~~ To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay Subject: Reporting Well Control Incident b~ ~ ~ `~~ Hi Jim, I was notified by BPXA Rep. Blair Neufeld this morning at approx. 1:00 a.m. that Nabors Rig 2ES had taken a 10 BBL gain & shut the BOPE on well 2-28A (50 psi casing) and was circulating out gas that they encountered after drilling out a downhole plug. I asked them to send us a more detailed email when conditions permit. Thanks, Jeff 5/15/2008 Sundry # 308-140 (02-28A RWO) Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, April 30, 2008 8:15 AM To: 'Peltier, Travis M' Cc: NSU, ADW Drlg Rig 2es; Hobbs, Greg S (ANC) Subject: RE: Sundry # 308-100 (02-28A RWO}--PTD 204-164 Travis, This is not an issue. I believe it is the standard practice to test the annular to 2500 psi. Nothing further is needed. I will place a copy of this message in the file. Also, please include the permit number in the subject line. Tom Maunder, PE AOGCC From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Wednesday, April 30, 2008 7:02 AM To: Maunder, Thomas E (DOA) Cc: NSU, ADW Drlg Rig 2es; Hobbs, Greg S (ANC} Subject: Sundry # 308-100 (02-28A RWO) ~~Et~ APR 2 9 20Q8 Tom, Step one of our proposed procedures states: 1) MIRU Nabors 2ES. ND Tree. NU and test BOPS to 250 psi tow, 3500 psi high. Circulate out freeze protection fluid and circulate well to clean 9.8 ppg brine. I am looking to change the third sentence to: NU and test BOP to 250 psi low, 3500 psi high, but test the annular preventer to 250 psi low, 2500 psi high. Thanks. -Travis Peltier BPXA Drilling Engineer (907)564-4511 4/30/2008 Sundry #308-100 (02-28A RW~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, April 09, 2008 4:13 PM To: 'Peltier, Travis M' ; Cc: Hobbs, Greg S (ANC) Subject: RE: Sundry #30$-100 (02-28A RWO) (204-'} Travis, I don't see any of this as an issue. Best regards, Tom Maunder, PE AOGCC From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Wednesday, April 09, 2008 4:09 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: Sundry #308-100 (02-28A RWO) ~~~~Et~ APR 0 9 2008 Tom, Im looking to change the pre-rig work request. For #1, I eliminated running a caliper as we already have one for this well. For #2, I had the naming of the downhole equipment wrong for the OTIS packer and Chem Injection Mandrel. I incorrectly listed those as a SBR and Camco valve. Unless you have any objections, I will change this in the workover program. -Travis Peltier GPB Rotary Drilling BP Alaska (907}564-4511 Pre-Rig Work Request (Proposed): S 1 Drift tubing for plug setting and tubing cut to 8983' MD. Set 2-7/8" Liner Top Test Plug (LTTP) at 8983' MD on 2.70" BKR Sleeve. Dump 10' sfuggits on top of plug. E 2 Jet cut 3 '/z" tubing @ 8888' MD (Ref original completion tubing tally). Jet cut desired to be in the middle of the full joint between OTIS packer and the upper Chemical Injection Mandrel. 4/9/2008 • • ~~, Y "~~ ~ ~ ~~~g~ij L ~ ~ ~ ~ ~ ~~' (~ SARAH PALIN, GOVERNOR .~~ ~. L1l~-7~[1 OI~ ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATI021T CODIM1551O1Q ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~~~~~~~~~ APR ® ~ 200 Re: Prudhoe Bay Field, Prudhoe Bay Pool, 02-28A Sundry Number: 308-100 ~ ~ L~- a,o ~" Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~ DATED this 2nd day of April, 2008 Daniel T. Seamount, Jr. Chair Encl. 0~ • STATE OF ALASKA ~/D~ ~~~~"~~~ (~ l ~ .'li ALASKA OIL AND GAS CONSERVATION COM SION MAR 2 7 2 ~ ~ APPLICATION FOR SUNDRY APPROVAL ~'~ 20 AAC 2s.2so Alaska Oil 8 Gas Cons. Cam 1. Type of Request: ^ Abandon D Suspend ^ Operation Shutdown ^ Perforate D Tim 51619e I ~~ ~ ®Alter Casm" g' ® Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ~ / D Change Approved Program ~Q P,y~ll T ub ing ^ Perforate New Pool ^ Waiver ^ Other ~ ^ ~ 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 204-164 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22012-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 02-28A - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028308 62' Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11728 8982 _ 11692 ~ 8981' None None Casin Len th ize MD TVD Burst Colla se Structural Conduct r 112' 20" 112' 112' 1490 47 Surface 3488' 10-3/4" 3488' 3488' 3580 2090 Intermediate 9301' 7-5/8" 9301' 8345' 6890 4790 Prod cti n Liner 1223' 5-1/2" 8993' - 9839' 8100' - 8801' 7740 6280 Liner 2745' 2-3/8" 8983' - 11728' 8092' - 8982' 11200 11780 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10350' - 11650' gggg~ _ 8979' 4-1/2". 12.6# x 3-1/2", 9.3# L-80 9028' Packers and SSSV Type: 7-5l8" x 3-1/2" Otis'BWD' packer Packers and SSSV MD (ft): 8918' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: May 15, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Travis Peltier, 56a-4511 Printed Name Greg bb f Title Engineering Team Leader Prepared By NamelNumber: Signature Phone 564-4191 Date ~~~',;+;' Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~ ~ ®~~S c ~~ ~~C~'~ Subsequent Form Required: ~{' APPROVED BY A roved B : COMMISSIONER THE CO MISS ON Date Form 10-403 Re~isZSd d6~2006 ~ ~~~ ~ ~~~~ ~•-,.--~8ul~mit Ir<Duplicate ~RIGII~AL • by cry, , 02-28A Rig Workover Well Type: Producer Current Status: This well is completed with 4-1/2" x 3-1/2" L-80 tubing and is currently shut-in with a 7-5/8" PC leak. Request: Repair well Scope of Work: Pull 4-1 /2" x 3-1/2" L-80 completion, run 5-1/2" scab liner from 8886' to 3750' and cement to 7-5/8" PC to cover cretaceous leak. Update FMC wellhead as necessary, including change out of 9 5/8" pack- offs, run 4-%2" x 3'/2" Chrome completion. MASP: 2420 psi Estimated Start Date: May 15, 2008 Intervention Engineer: Travis Peltier Production Engineer: James Dean Pre-rig prep work: S 1 Drift tubing for caliper survey and tubing cut to 8983' MD. Caliper tubing from surface to 8983' MD. Set Liner Top Test Plug (LTTP) at 8983' MD on 3-1 /2" BKR Sleeve. Dump 10' sluggits on to of lu . E 2 Jet cut 3-%2" tubing @ 8888' MD (Ref original completion tubing tally). Jet cut desired to be in the middle of the full 'oint between SBR and u er Camco ni le. F 3 Circulate well with -9.8 ppg NaCL brine and cap with diesel thru the cut. MITOA to 2000 psi. Bleed WHPs to 0 psi. Establish injection pressures @ 1 bpm and 2bpm for scab liner cement design. No CMIT re wired due to PC leak. O 4 Set a BPV in the tubin han er. O 5 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure: 1. MIRU Nabors 2ES. ND tree. NU and test BOPE to 250 psi low, 3500 psi high protection fluid and circulate well to clean 9.8 pgg brine. 2. Pull and LD 4-%2" x 3-%2" tubing string. 3. Cleanout 7-5/8" casing to the cut and dress-off stub. 4. Run 5-%2" scab liner with 7-5/8" x 3'/2" overshot to 3750'. 5. Cement 5-%2" scab liner. 6. Run new 4'/z" x 3-%2" Chrome tubing completion with packer at -8826'. 7. Displace the IA to packer fluid and set the packer. 8. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 9. Set BPV. ND BOPE. NU and test tree. RDMO. Circulate out freeze ATTACH: Current Schematic Proposed Schematic TREE= 4" CAMERON WELLHEAD = FMC AL;TUATOR = AXELSON KB. ELEV = 62.0' BF. ELEV KOP = 4100' Max Angle = 95 @ 10756' Datum MD = 9908' Datum TV D = 8800' SS 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" I-i 2208' ESTIMATED CMT TOP ~ 2985' 10-314" CSG, 45.5#, J-55, ID = 9.953" 3485' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 4689' Minimum ID =1.92" @ 8990' TOP OF 2-3/8" LINER TOP OF 5-1/2" LNR I-i 8993' o2-is 2186' 4-1/2" AVA TRSV SSSV NIP, ID = 3.812" 2208' 4-1/2" X 3-1/2" XO, ID = 2.867"1 GAS LIFT MANDRELS C ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3189 3189 1 MMG DMY RK 0 03/01/92 2 5206 5104 35 MMG DMY RK 0 09/25/94 3 6604 6217 37 MMG DMY RK 0 4 7098 6603 38 MMG DMY RK 0 5 7405 6847 38 MMG DMY RK 0 6 8238 7505 38 MMG DMY RK 0 7 8487 7700 38 MMG DMY RKP 0 ( :HF-MICR 1 MH NUKFI ?J ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 8827 7969 38 MMG CIV RK 12 11/18/90 8918' 7-5/8" X 3-1/2" OTIS BWD PKR, ID = 4.00" 8983' 2.70" BKR DEPLOY SLV, ID = 2.250" 13-1/2" OTIS XN NIP, ID = 2.75" (BEHIND PIPE) I 'I 3-1/2" TBG-PC, 9.3#, L-80, .0087 bpf, ID = 2.992" (- 9028' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 9300' TOP OF CEMENT 9600' 5-1/2" WHIPSTOCK (11/28/04) 9835' PIP TAG 9842' PBTD 10167' 5-112" LNR, 17#, L-80, .0232 bpf, ID = 4.892" 10216' TD 10221' MILLOUT WINDOW (02-28A) 9839' - 9845' PBTD 11692' 2-3/8" LNR, 4.7#, L-80 STL, .0039 bpf, ID = 1.995" 11728' PERFORATION SUMMARY REF LOG: SWS MEMORY CNL/GR/CCL ON 12/11/04 ANGLE AT TOP PERF: 87 @ 10350' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1-9118" 6 10350 - 10660 O 12!11 /04 1-9/16" 6 10750 - 10880 O 12/11/04 1-9/16" 6 11080 - 11425 O 12/11/04 1-9116" 6 11575 - 11650 O 12/11/04 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/17/90 ORIGINAL COMPLETION 12/12/04 NORDICI CTD SIDETRACK (02-28A) 03/16/06 RPI-~UTLH WANERSAFETY NOTE 08/26/06 ITCH DRLG DRAFT CORRECTIONS 08/27/06 ITCH CHEM INJ V LV FORMAT ._.._.._ _....__.__.__.. PRUDHOE BAY UNIT WELL: 02-28A PERMff No: 2041650 API No: 50-029-22012-01 SEC 3, T11 N, R14E, 2122.28' FEL & 3777.19' FNL BP Exploration (Alaska) 9028' ~3-1/2" WLEG, ID = 2.97" (BEHIND PIPE) 9027' ELMD TT LOGGED 05/08/90 /~LFEAU = rM~; GTUATOR = AXELSON B. ELEV = 62.0' F. ELEV = OP = 4100' tax Angle = 95 ~ 10756' latum MD = 9906' Tatum ND = 8800' SS 41/2" TBG-PC, 12.6#, 13CR, .0152 bpf, ID = 3.958" ESTIMATED CMT TOP 45.5#, J-55, ID = 9.953" SAF P3: IA G~ SQZ (5970'-8050'). ""'PRODCSG 2-28A RWO LEAKOP6tATINGLIMIT3: MAXU4P=500 PSI, MAXOJIP =1000 PSI (02120108 WAN6ia DOMT RUN LGLV's, IA LOAD®W/BIaNEOVHtCRET LEAK 70° ~ -x10098' 2188' 4-12" X NIP, ID = 3.812" ,208' 2208' 4-1/2' X 3-1/2" XO, ID = 2.887" r-0A S I IFT MA NDRFLS I 2985' (• ST MD ND DEV TYPE VLV LATCH PORT DATE 1 2 3351 6112 3350 5822 MMG KBG-2 Tap Btm 16 20 17-5/8" X 5-1/2' Packer I 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 5-1/2' 17#, L-80, STL, ID = 4.892" 5-112" x 3-12" Pbrted XO Top of 2 x 10' 3-117' Plrps 7-5l8" z 3-12" Overshot 3-1/2" Stub ID=8.875" 4889' 8860' 8860' ITOPOF 5-1/2' LNR H 8893' Minimum ID = 1.92" ~ 8990' TOP OF 2-3/8" LINER 13-12" TBG•PC, 9.3#, L-80, .0087 bpf, ID = 2.992" H 9028' 7-5/8" CSG, 29.7#, L-80, ID = 8.875" 9300' TOP OF C9NENT 9600' 5-112" WHIPSTOCK (1128/04) 9835' PBTD L-80, .0232 bpf, ID = 4.892" PERFORATION SUMMARY REF LOG: SWS MEMORY CNUGR/CCL ON 12/11/04 ANGLE AT TOP PERF: 87 ~ 10350' Note: Refer to Production DB for historical pert data SIZE SPF NVT9~1/AL OpNSgz DATE 1-9/16" 6 10350- 10660 0 12/11/04 1-9/15' 6 10750 - 10880 O 12/111'04 1-9/16" 6 11080 - 11425 O 12/11104 1-9/15' 6 11575 - 116,50 O 12/11104 1016T 10216' 10221' 4.7#, 3-1/2' X Nip,ID = 2.813" 5-12" X3-12" Baker SABL-3 9CR 312" XN Nip, ID = 2.75" 7-5/B" X 3-12" OTIS BWD PKR, II 2.70" BKR DEPLOY SLV, ID = 2.2 13-1/2' OTIS XN NIP, ID = 2.75" (BBiIND PIPE) I 9028' H3-12" WLEG, ID = 2.9T' (BAND 9027' ELMD TT LOGGED 05/08/90 DATE REV BY COMMENTS DATE REV BY COMMENTS 03M7190 ORIGINAL COMPLETION 12f12/04 NORDICI CTDSIDETRACK(02-28A) 03/16/06 RPHITLH WANER SAFETY NOTE 0826/06 /TLH DRLG DRAFT CORRECTIONS 0827/06 lTLH I.^,HEM INJ VLV FORMAT MILLOUT WINDOW (02-28A) 9839' - 9845' PBTD 11682' = 1 C95" ~ ~ 7'M' PRUDFIOE BAY UNIT WELL: 02-28A PlA11AT No: 2041650 API No: 50-029-22012-01 SEC 3, T11 N, R14E, 2122.28' FEL 8 3777.19' FNL BP 6cploratlon (Alaska) • .. i. A~--y,. w.' ~'V`, aP'~ MICROFILMED 03/01/2008 • DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:lLaserFichelCvrPgs_InsertslMicrofilm_Marker. doc 02-28A (PTD #2-Elnternal fiver Cancellation -Not Operable Well Page 1 of 1 ~}- f 6 ~- r Regg, James B (DOA) From: Lau, John, Jack [IaujjO@BP.com] on behalf of NSU, ADW Wel{ {ntegrity Engineer ~ ~(~~,`~ [NSUADWWeIIlntegrityEngineer@BP.comJ ~~~~ 1 Sent: Monday, December 31, 2007 6:01 AM To: NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, FS1 DS Ops Lead; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, Wells Opt Eng; GPB, EOC Specia{ists; Enge{, Harry R; Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Dean, James A; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Lau, John, Jack; Holt, Ryan P (ASRC); Dahlem, Jason E Subject: 02-28A (PTD #204165~Oj Internal Waiver Cancellation -Not Operable Well 'ZsJ4-lam All, An internal waiver was issued for a PC Leak on natural producing well 02-28A (PTD #2.0~1~6'j on 02/20/06. The dispensation from the Well Integrity System Policy for this well has expired. If not already done, please ensure the well has been shut-in by the end of today and arrangements have been made to freeze protect the well. 02-28A has been reclassified as Not Operable. A secure program will be sent shortly. Please remove all Waivered well signs and the laminated copy of the waiver from the wellhouse. Please call if you have any questions. Thank you, Jack Lau (for Anna Dube) Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 - ~p~ ~ ~: ~0(~~ t~' 1!16/2008 )/.-.. j~ ~ì DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Permit to Drill 2041640 Well Name/No. PRUDHOE BAY UNIT 02-28A MD 11728 TVD 8982 Completion Date 12/12/2004 REQUIRED INFORMATION Mud log No -~-,-~~- DATA INFORMATION Types Electric or Other Logs Run: MWD / NGP GR / ROP, MGR / CCl I CNl Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name MD Asc Directional Survey Ú;/D Asc Directional Survey og Neutron 1J2ff C Lis 13219 Gamma Ray 1cf26 D Lis 13284 I nd uction/Resistivity ~ 13284 LIS Verification ~ D Lis 13285 I nd uction/Resistivity µ 13285 LIS Verification C Lis 13601 Gamma Ray Operator BP EXPLORATION (ALASKA) INC Completion Status 1-01l API No. 50-029-22012-01-00 .._~- Current Status 1-01L .-.~-~- UIC N Samples No .- _._-~-- --_._--,- Directional Survey Yes --~- (data taken from logs Portion of Master Well Data Maint Log Log Scale Media Interval Start Stop 9982 11728 9807 11157 8790 11677 8790 11677 Run No L.....__... Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORM~'lON Well Cored? Y lB> Chips Received? Y I ÞI Analysis Received? Y~· 2 Blu 9753 11702 9753 11702 9753 11136 9753 11136 9845 11728 ~--_._~---------~--_.. OH/ . CH Received Comments 1/27/2005 IIFR . . 1/27/2005 PB 1 2/3/2005 cnl/mem grlccl Case 815/2005 MCNl I Open 9/26/2005 GR ROP I Open 9/26/2005 GR ROP Open 9/26/2005 PB 1 GR ROP Open 9/26/2005 PB 1 GR ROP I Open 2/22/2006 ROP NGP plus Graphics / I PB 1 9845-11157 ROP I NGP plus Graphics ._~----~- -~----"-,~_.._----' Sent Received Sample Set Number Comments . Daily History Received? ~/N ((9N Formation Tops -"--------~~- _._~---~------_.,._--------~_.-._--~--_.. --~-_.- Comments: ----" --~--~-_..._-~_. ._~-~"----_.,-~-_._.- Permit to Drill 2041640 DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Well Name/No. PRUDHOE BAY UNIT 02-28A Operator BP EXPLORATION (ALASKA) INC MD 11728 TVD 8982 -"-~----~ Compliance Reviewed By: Completion Date 12/12/2004 Completion Status 1-01L Current Status 1-01L jf:o .._~~- Date: API No. 50-029-22012-01-00 UIC N !fJ~~-,;'~ . . . . WELL LOG TRANSMITTAL ;)04 ~ 1&,4- } 3å> 0 ( February 16,2006 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 02-28A + PB1, 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 02-28A + PBl: LAS Data & Digital Log Images: 50-029-20012-01, 70 5b~D~q-,}:;2DI2-ûf) 1D 1 CD Rom ~~ . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 4, 2005 RE: MWD Formation Evaluation Logs: 02-28A, AK-MW-341 0649 1 LDWG formatted Disc with verification listing. API#: 50-029-22012-01 tÞ I '3> Æ 8\{ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro- Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: ~ 1- Signed: f¡ 0 c.{--- { ~ ~ . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West ih Avenue, Suite 100 ~chorage,Alaska 99501 August 4, 2005 RE: MWD Formation Evaluation Logs: 02-28A PBl, AK-MW-3410649 1 LDWG formatted Disc with verification listing. API#: 50-029-22012-70 -# 15~¡~- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro- Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:Åb W~\ Signed: 1J ~}jj ÂDc.{-/~tj 08/04/05 Scblumberger NO. 3447 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ..." Well .. Job# Loa Description Date o or ; MPF-57A ~O.>~ le7 10672349 CHANNEL DETECTION LOG 01/24/04 1 / 02-28A 1J,. 0 II .~ í (p t.j 10928607 MCNL 12111/04 1 )IC{ . ;/ DS 18-23A I G{ "3 -ICI I 10942206 MCNL 04/20/05 1 1 '~:2J!< /OWDW-SE joc- 1.)'1 10893097 RST-BORAX CHANNEL DETECTION LOG 03/25/05 1 1 JJf' v E-23B 1'1<\,,· ',i '\ 10889133 LEAK DETECTION LOG 07116/04 1 v E-238 \.,"" . .,., ~ 11039119 LEAK DETECTION LOG 05/08/05 1 G P-06A ¡ C¡ 7-;" J,....., N/A LEAK DETECTION LOG 06/04/05 1 ¡,/ Y-09A q 7 - OJ] 10942222 MEM PPROF W/DEFT 07/14/05 1 If' P2-49 Ie 1..0).,-/ 11062633 PRODUCTION PROFILE W/DEFT 07102/05 1 , DS 04-23A 'i 3,· j}) 11051072 PRODUCTION LOG WIDEFT 07/13105 1 ... 'D.S.16-01 O-J 3(.;¡ 1105228 INJECT/ON PROFILE UTe 07/21105 1 ./ 4-10A/L-28 .2 J).-2~ 3 10662991 RST 02/05104 1 ./ 01-49IP-21 I 'S- 0 7:g 11072870 PRODUCTION PROFILE W/GHOST 07/11/05 1 01-57/R-23 I¡ ['I , J,. /'....1 11072871 PRODUCTION PROFILE W/GHOST 07/12/05 1 BL C CD . . Date Delivered: :2 11.1 JJo ~ - Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 9~~3-~38 1'.!tÍ. ATTN: Beth .r.- 1/ /1/ '/ II iLl If ' Received by: ¡" fIf"&~ /, BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ·,r t;;;2z; V:' ~ ,/6" f 01/24/05 Schlumberger NO. 3318 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . /f:~ ~ t n'l- /) fqð~Cz 1.J)f~ {4 -"e-ot /1'1'1-0 (; 1Pf. ø ,9,-() ;).Oq·1.Ð ~()i{~ I~ 2D" -ðW ~~ ¡'S- (~3 lC~ Well Job# Loa DescriDtion Date ue me rIOts '7c C-29A 10715422 MCNL 08/20/04 1 ì E-25 10715423 MCNL 08/21/04 1 q G-02A 10715424 MCNL 08/23/04 1 W-27A 10670031 MCNL 08/24/04 1 t~ D-25A r__. 10854314 MCNL 08/27/04 1 ,1; DS 15-25A "" 10715428 MCNL 09/11/04 1 ,1ft E-39A 10715430 MCNL 09/13/04 1 02-16B 10928597 MCNL 10/02/04 1 (I C-25A 10928598 MCNL 10/03/04 1 1 E·17A 1 10928602 MCNL 10/30/04 1 ~ C-41A I 10928606 MCNL 11/24/04 1 ,- DS 07 -30A '7 10715445 MCNL 12/09/04 1 rl. DS 15-38A ¡¿ 10715446 MCNL 12/11/04 1 ;;f 02-28A 10928607 MCNL 12/11/04 1 D-11A 10928608 MCNL 12/16/04 1 ~ DS 05-24A 10928609 MCNL 12/22/04 1 Prints_ onlv·Job not comDlete) BI r Color p' CD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 900 E, Benson Blvd, Anchorage, Alaska 99508 Date Delivered: ;;¿J; jo:r I Alaska Data & Consulting Services 2525 Gambell Street, SuityttOO ~~~K "ï" ReC~t3d by: \ '. , ~ G/ . STATE OF ALASKA a ALAS~IL AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG D .IAN ~ .;., , '",,', .i, (' G¡iH: I}'~H;. 1a, Well Status: 181 Oil o Gas o Plugged o Abandoned o Suspended o WAG 1 b. Well Class: };,ni;!-¡¡¡¡:WQ€: 20MC 25,105 20MC 25.110 181 Development 0 Explo"ratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 12/12/2004 204-164 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 11/30/2004 50-029-22012-01-00 4a, Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 12/9/2004 PBU 02-28A 273' SNL, 796' EWL, SEC. 36, T11 N, R14E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 1522' NSL, 2071' WEL, SEC. 26, T11N, R14E, UM 62' Prudhoe Bay Field I Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 1568' NSL, 3161' WEL, SEC. 26, T11N, R14E, UM 11692 + 8981 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 687530 y- 5950926 Zone- ASP4 11728 + 8982 Ft ADL 028308 TPI: x- 684617 y- 5952650 Zone- ASP4 11, Depth where SSSV set 17. Land Use Permit: --~ ~~ (Nipple) 2186' MD Total Depth: x- 683527 y- 5952669 Zone- ASP4 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost 181 Yes ONo NIA MSL 1900' (Approx.) 21, Logs Run: MWD / NGP GR / Rap, MGR I CCL / CNL 22. ('ASING, LINER AND CEMENTING RECORD CASING . ::>ËTJING 'PEFn'H MD 'SETTING DEPTI-I TVD HoLE T ~ SIZE Wr. PER F'T. GRADE Top BöTTOM Top I BöTTOM SIZE 20" 91.5# H-40 Surface 112' Surface 112' 30" 2150# Poleset 10-3/4" 45.5# J-55 Surface 3488' Surface 3488' 13-1/2" 1000 sX CS III, 350 sX 'G'; Top Job; 152 sX CS II 7-5/8" 29.7# L-80 Surface 9301' Surface 8345' 9-7/8" 450 sx Class 'G' 5-1/2" 17# L-80 8993' 9839' 8100' 8801' 6-3/4" 125 sx Class 'G' 2-3/8" 4.7# L-80 8983' 11728' 8092' 8982' 3" 77 sx Class 'G' 23. Perforations op'en to Production (MD + TVD of Top and 24. · T JBING Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 1.56 Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 2208' MD TVD MD TVD 3-1/2", 9.3#, L-80 2208' - 9028' 8918' 10350' - 10660' 8988' - 8996' 25. ACID, FRACTlJRi:,GEMeNT 10750' -10880' 8992' - 8987' i ) 11080' - 11425' 8982' - 8980' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11575' - 11650' 8977' - 8979' 2500' Freeze Protect w/ MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): December 23, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF W A TER-BBl CHOKE SIZE I GAS-all RATIO 1/8/2005 12.1 TEST PERIOD ... 700 70 .5 81.86 100 Flow Tubing Casing Pressure CALCULATED ... Oll-BBl GAs-McF W A TER-BBl all GRAVITY-API (CORR) Press, 224 100 24-HoUR RATE 1,389 139 13.85 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit.corechips; if none, state "none". RBDMS BFt ,iAN 1 8 Z005 ."'"". None ! ~/;¡¿¡ J~._! (ì [) 1 i ,_, j f\l/\ &1; ')<"~- ..."'-.,.....,..,.,"'.....(""''';'^.~/ Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28; GEOLOGIC MARKE 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Zone 2B 9876' 8832' None Zone 2A 9937' 8878' Zone 1 B 10016' 8930' Zone 1A 10047' 8949' 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 knowtedge. Signed Terrie Hubble Title Technical Assistant Date 01../0 "OS PBU 02-28A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Mark Johnson, 564-5666 204-164 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None", Form 10-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-28 02-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/17/2004 Rig Release: Rig Number: N1 Spud Date: 2/27/1990 End: 11/26/2004 I 17:30 - 18:00 0.50 I MOB P PRE Rig released from C-41A @ 17:30Hrs on 11/27/2004. Prep to 18:00 - 20:00 I move rig off well. Roll up tarps & RID rig camp, 2.00 I MOB P PRE Warm up hydraulics. RID outside equipment. 20:00 - 20:30 0.50 MOB P PRE Move rig off off well. Conduct post-operations pad inspection. I Move rig to pad entrance, 20:30 - 21 :00 0,50 I MOB P PRE Held pre-move safety meeting with rig crew, Pad operator, Tool Services & Security, 21 :00 - 00:00 3,00 MOB P PRE Moving rig from C-pad to DS#02, 11/27/2004 00:00 - 05:00 5.00 MOB P PRE Moving rig from C-pad to DS#02. 05:00 - 06:00 1.00 MOB N WAIT PRE W. O. rig mats to be placed on flowline. 06:00 - 09:00 3,00 MOB P PRE Moved rig to DS#02. 09:00 - 09:30 0.50 MOB P PRE SAFETY MEETING. Review procedure, hazards & mitigation for backing rig over well, 09:30 - 10:30 1.00 MOB P PRE ACCEPT NORDIC-1 ON 02-28A & AL 1 @ 09:30Hrs, 11/27/04. N/D tree cap & open up well. Observe 1500psi WHP (WHP was incorrectly checked prior to moving onto the well). Mobilize LRS & KCL fluid for a reloadlwell kill prior to N/U BOPE. 10:30 - 13:00 2.501 MOB N WAIT PRE W. O. KCL fluid to arrive location. Meanwhile spot outside 2.00 I KILL trailers. R/U & PIT hardline to flowback tank. 13:00 - 15:00 N DPRB PRE Load & kill well with 290bbls of 1% KCL. Injectivity = 5bpm/1880psi. 15:00 - 17:30 2.50 MOB P PRE N/U BOPE. 17:30 - 00:00 6.50 BOPSU P PRE R/U & perform initial BOPE pressurelfunction test to 400 psi low I 4500 psi high as per permit (annular to 250 psi low I 2500 psi high). - AOGCC Rep Jeff Jones to witness. 11/28/2004 00:00 - 02:00 2.00 BOPSU P PRE R/U & perform initial BOPE pressure/function test to 400 psi low I 4500 psi high as per permit (annular to 250 psi low I 2500 psi high). - AOGCC Rep Jeff Jones to witness, - Open well, on a vaccum, Fill hole. 02:00 - 04:30 2,50 WHIP P WEXIT Spot and rig up SLB wireline unit. Bring tools to rig floor. M/U Baker 3-1/2" x 5-1/2" whipstock & setting BHA with SLB E-Line WPPT tool. Insure integrity, Place pip tags. From TOWS to RA pip tag = T. - Hole still taking fluid at 2 bpm, 260 bbls total. Bringing rate up to 4 bpm. 04:30 - 06:00 1.50 WHIP P WEXIT RIH with WS and setting tool. - Established circulation, still losing fluid at 3,3 bpm. 06:00 - 07:30 1,50 WHIP P WEXIT Log GR/CCL & tie-into SLB CBT log of 03/24/90. Correct ELMD by 0.5'. Orient WIS tray with SLB WPPT tool to 15R. Set W/S @ 15R with top @ 9835' & observe wt loss, SIO - WIS taking wt. Log off. 07:30 - 08:30 1.00 WHIP P WEXIT POOH with E-Line setting tool. 08:30 - 09:00 0.50 WHIP P WEXIT UD E-Line tools & RDMO SLB E-Line unit. 09:00 - 09:15 0.25 WHIP N THAW WEXIT Attempt to displace CT FP - observe ice plug in CT. M/U nozzle to CT. M/U injector & RIH to 110', Maintain 4000psi in CT & pump down the backside. Thaw out ice plug in CT. POH. SI swab. 09:15 - 09:45 0.50 WHIP P WEXIT Circ & displace FP fluid from CT, 09:45 - 10:00 0,25 WHIP P WEXIT Open up well & SI choke, Bullhead down the CT @ max rate. Observe no +ve WHP. Call for diesel truck for cement job. Meanwhile R/U SLB Cementers. Printed: 12/14/2004 8:22:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-28 02-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/1 7/2004 Rig Release: Rig Number: N1 Spud Date: 2/27/1990 End: 11/28/2004 10:00 - 10:50 0.831 WHIP P WEXIT SIB injector & cut CT. GBR install weld-on CTC, Pull test to 40k & P/test to 4000psi. 10:50 - 11 :00 0,17 ZONISO P WEXIT M/U slick cementing BHA with nozzle, 1-1/4" stinger Xlover to CTC, M/U injector. 11 :00 - 13:20 2.33 ZONISO P WEXIT RIH with cementing BHA #1 circ @ 1,28bpm with no returns. Wt check below tbg tail & PUH to ensure no O/Pulls. Run-in wt = 18.5k. Saw slight wt bobble - +1-300Ibs set down @ 9831' & 400lbs set down @ 9835'. Observe wt break back again to 18.5k. Seems like we may be pushing down whipstock? RIH to 9856'. PUH 40', RBIH & saw +1-400Ibs set down @ 9856'. Continue RIH & finally tag with 2-3k set down wt @ 9862' (Note that there is a csg collar @ +1-9862'). MWD depth reads 9862' & mech depth counter reads 9867'. Review situation with BOT I & ANC. Decide to POH & RIH for MWD tie-in. 13:20 - 15:00 1.671 ZONISO N DFAL WEXIT Paint EOP flag @ 9750', POH with cementing BHA #1. Had 12.5' depth @ surface - BHA length is 11', 15:00 - 15:30 0,50 ZONISO N DFAL WEXIT UD cementing BHA#1, GPB currently in Phase-1 driving conditions. 15:30 - 16:00 0.50 WHIP N DFAL WEXIT M/U MWD tie-in BHA #2 with nozzle, MWD & MHA. M/U injector. 16:00 - 17:35 1.58 WHIP N DFAL WEXIT RIH with MWD tie-in BHA #2, Correct CTD by -5' @ the flag. RIH & tag whipstock @ 9868', SLB mech depth counter reads 9865'. PUH to 9780' for GR tie-in log, GPB currently in Phase-2 driving conditions, 17:35 - 19:00 1.42 WHIP N DFAL WEXIT Log down GR & tie-into SLB CBT log of 03/24/90. Correct CTMD by -29', Confirm whipstock has not traveled, TOWS at 9835' MD. - GPB currently in Phase-2 driving conditions, - Review with ANC, Change cement to include 15 ppb aggregate in 8 of 15 bbls. 19:00 - 21 :00 2,00 WHIP N DFAL WEXIT POOH. 21 :00 - 22:00 1.00 ZONISO N DFAL WEXIT LD logging BHA. PU cement nozzle/stinger. 22:00 - 23:30 1.50 ZONISO N DFAL WEXIT RIH circulating at 2.7 bpm, 3360 psi. - Caught fluid, getting 0,25 - 0,5 bbls return flow, 23:30 - 00:00 0,50 ZONISO P WEXIT Hold PJSM with cementers 11/2912004 00:00 - 01 :00 1,00 ZONISO P WEXIT Batch mix 15 bbls 15.8 ppg cement. Pump 45 bbls of diesel down the backside -1.3bpm, 170 psi. - 70 psi shut in pressure, 01 :00 - 02:00 1,00 ZONISO P WEXIT Pump P&A cement at 1.3 bpm, 1100 - 1800 psi. - Pump 4.4 bbls water spacer (73 degrees) - Pressure test lines to 4000 psi - Zero in MM at 15.8 ppg density - Pump 4 bbls neat cement - Pump 8 bbls cement with 15 ppb aggregate - Pump 3 bbls neat cement - Pump 5 bbls water spacer. - RIH pumping 1% KCI, place coil at 9830' MD. - Pump 2 bbls cement out nozzle. - POOH laying in cement 1: 1 to 8600' (full returns with 5 bbls out of nozzle) 02:00 - 03:00 1,00 ZONISO P WEXIT At safety, establish circulation. Shut in backside. Increase pressure to 500 psi (took 0.7 bbls), Hold. Printed: 12/14/2004 8:22:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-28 02-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/17/2004 Rig Release: Rig Number: N1 Spud Date: 2/27/1990 End: 03:00 - 04:30 1.50 I ZONISO P WEXIT 04:30 - 06:45 2,25 ZONISO P WEXIT 06:45 - 07:45 1.00 ZONISO P WEXIT 07:45 - 08:00 0.25 STWHIP P WEXIT 08:00 - 08:45 0.75 STWHIP P WEXIT 08:45 - 10:45 2.00 STWHIP P WEXIT 10:45 - 11 :00 0.25 STWHIP P WEXIT 11 :00 - 11: 15 0.25 STWHIP P WEXIT 11:15 -12:15 1,00 STWHIP P WEXIT 12:15 - 13:30 1.25 STWHIP P WEXIT 13:30 - 14:45 1.25 STWHIP P WEXIT 14:45 - 15:50 1.08 STWHIP P WEXIT 15:50 - 16:35 0,75 STWHIP P WEXIT 16:35 -17:15 0.67 STWHIP P WEXIT 17:15 - 18:30 1.25 STWHIP P WEXIT 18:30 - 21:00 2.50 STWHIP P WEXIT 21 :00 - 22:30 1.50 STWHIP P WEXIT 22:30 - 23:00 0,50 STWHIP P WEXIT 23:00 - 23:30 0.50 STWHIP N RREP WEXIT 23:30 - 00:00 0.50 DRILL P PROD1 11/30/2004 00:00 - 00:30 0,50 DRILL P PROD1 00:30 - 02:00 1.50 DRILL P PROD1 Increase pressure to 1000 psi (took 0,6 bbls), Hold. Crack choke and bring up rate to establish 1000 psi squeeze pressure (prevent freezing coil). Close choke, increase pressure to 1000 psi for 5 minutes to confirm holding, Open choke to maintain 500 psi on the well while swapping well over to 2 ppb Bio water for window milling. - Pumping at 2,3 bpm. - RIH washing cement to 9825' MD, - Drop ball to divert flow through nozzle, POOH with nozzle washing jewelry. OOH, S/I master, jet stack & flush surface lines. CIO packoff. CIO SLB depth encoder, POOH & UD nozzle BHA. SIB injector. Held pre-operations safety meeting. Reviewed well plan, potential hazards & BHA M/U procedures. M/U window milling BHA #4 with HCC 2.74" DWM, 2.74" diamond string mill, Baker extreme straight motor, MHA & 2 jts of 2-1/16" CSH tbg, Stab injector on well. RIH window milling BHA #4. Tag cement/bridge @ 9820'. Cmt has been in place now for 8.5 hours, SI choke & P/test well bore to 1000psi for 10mins - OK. SLB Lab confirms 900psi compressive strength after 8 hours. Mill soft cmt with 1,53bpm/1600psi, <1k WOB & 60fph. Tag WS/Lnr pinch pt & stall @ 9824', Flag pipe & correct depth to 9838,7' (pinch pt ELMD), Start milling window with 1,56/1,56bpm 1600/1850psi, 1-2k WOB. Mill to 9840'. Mill to 9840.9' with 1.56/1.56bpm 1600/1950psi, 1 k WOB. Stall @ 9840,9'. P/U & ease-into milling from 9840'. Mill to 9841'. Mill to 9842' with 1 ,52/1 ,52bpm 1790/1830psi, 1.2k WOB. Mill to 9843' with 1,52/1.52bpm 1790/1970psi, 1 k WOB. Should be at window center pI. Seeing metal shavings on the ditch magnets. Time mill window to 9843,6' with 1.52/1.52bpm 1790/1930psi, 1k WOB. Stall @ 9843.6'. Should be close to BOW. P/U & ease-into milling from 9843'. Continue time milling window, Break into formation at 9845'. Tentative window depths are: TOWS = 9835', TOW = 9838.7'; BOW = 9845', RA PIP Tag = 9842'. Mill formation to 9856' with 1.52/1.52bpm 1790/1930psi. 1 k WOB, Dress window. Swap well over to reconditioned tlo pro. RIH, dry tag at TOWS. Stack 2500 Ibs on window. Dress again. Dry tag -- OK. POOH with window milling BHA. LD BHA #4 (2.74" go I 2.73" no-go), Repair valve on rig floor choke manifold, PU build BHA #5. MU BHA #5. RIH with BHA #5. SHT MWD and orienter at 4125' MD, no response. RIH to 4500' to SHT again at higher angle. Failed again. Printed: 12/14/2004 8:22:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-28 02-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/17/2004 Rig Release: Rig Number: N1 Spud Date: 2/27/1990 End: - This orienter was the same one used on C-41 A. It has been rebuilt and tested at surface and worked. - Will swap out MWD probe as well, not sending all of the magnetic information up. Needs reformatting, 02:00 - 02:45 0.75 DRILL N DFAL PROD1 POOH to change out orienter. 02:45 - 03:30 0,75 DRILL N DFAL PROD1 Change out orienter and MWD probe. 03:30 - 04:30 1,00 DRILL N DFAL PROD1 RIH with build BHA #6, SHT at 4300' MD. OK, 04:30 - 05:30 1.00 DRILL P PROD1 Continue to RIH to 9770' MD 05:30 - 06:00 0.50 DRILL P PROD1 Tie in to formation (REF: CBL 03/24/90 log). - Correct + 1.5' 06:00 - 06:15 0,25 DRILL P PROD1 Orient to HS. RIH through window. Tag TD at 9855' MD - PU 2.67k; SO 18k. Orient TF to 25R. 06:15 - 08:00 1,75 DRILL P PROD1 Drill ahead to 9906', - 3570 psi free spin - 3850 psi free spin -1.56/1.65 bpm - 20-50R TF 08:00 - 17:30 9.50 DRILL P PROD1 Orient & drill to 10200' with 20-60R TF, 1,60/1.60bpm 3570/3850psi, 2k WOB & 45fph ave ROP. 17:30 - 18:30 1.00 DRILL P PROD1 Wiper trip to window. 18:30 - 22:30 4,00 DRILL P PROD1 Directionally drill 1,61/1,71 3710 psi ,FS= 3650 psi. 3K WOB, ROP 40, drill to 10347. 22:30 - 23:00 0,50 DRILL P PROD1 Wiper to window. 23:00 - 23:25 0.42 DRILL P PROD1 Tie-in correction + 2'. 23:25 - 23:45 0.33 DRILL P PROD1 RIH 1.5 bpm tag at 10347.5' 23:45 - 00:00 0,25 DRILL P PROD1 Directionally drill 1,56/1,65 3850 psi ,FS= 3650 psi. 4K WOB, ROP 60, drill to 10361. 12/1/2004 00:00 - 00:30 0.50 DRILL P PROD1 Drill to 10,400', 00:30 - 02:30 2.00 DRILL P PROD1 POH for lateral drilling assembly. 02:30 - 03:30 1.00 DRILL P PROD1 BHA swap. Change out MWD, and bit. Dial motor down to 1.1 03:30 - 05:30 . 2,00 DRILL P PROD1 RIH.9880 05:30 - 06:30 1,00 DRILL P PROD1 Tie -in. Correction +20'. 06:30 - 06:50 0.33 DRILL P PROD1 Orient to 75 right. 06:50 - 08:00 1,17 DRILL P PROD1 Drill ahead at 70R to 10,500' MD - PU 29k; SO 14k - 1.6/1.7 bpm, 3400 psi - Free spin: 3100 psi - 3k WOB. - 100 fph avg ROP. 08:00 - 08:30 0,50 DRILL P PROD1 Orient TF to 80R. 08:30 - 09:15 0.75 DRILL P PROD1 Drill ahead at 80R to 10,549' MD - PU 29k; SO 14k -1.6/1.7 bpm, 3400 psi - Free spin: 3100 psi - 3k WOB. - 100 fph avg ROP. 09:15 - 10:00 0.75 DRILL P PROD1 Wiper trip to window, 10:00 - 13:30 3.50 DRILL P PROD1 Drill ahead at 130R to 10,608' MD - PU 29k; SO 14k - 1.7/1.8 bpm, 3200 psi - Free spin: 3000 psi - 5k WOB.c Printed: 12/14/2004 8:22:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-28 02-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/17/2004 Rig Release: Rig Number: N1 Spud Date: 2/27/1990 End: 12/112004 13:30 - 13:45 ' 0.25 DRILL P PROD1 Orienting to 90R, 13:45 . 19:30 5.75 DRILL P PROD1 Drill ahead at 130R to 10650' MD, - PU 29k; SO 14k - 1.7 11.8 bpm, 3300 psi - Free spin: 3100 psi I: - 5k WOB. 19:30 - 21 :00 1,50 DRILL PROD1 Drill shale 10,600 to 10,660. Set down 10660 possible ledge, Drill sand to 10690, Back in shales to 10,700' 21 :00 - 21 :50 0.83 DRILL PROD1 Wiper to window, Set down 10086, Motor work at 10660. 21 :50 - 00:00 2.17 DRILL P PROD1 Directionally drill 1.6 11.7 bpm @ 3150 psi, 2950 psi = FS, WOB 17K ,-3K surface wt, 27K up wt, ROP 5-10 in shales. 40-60 in sand. Per Geo no appearant dip, 12/2/2004 00:00 - 02:00 2.00 DRILL P PROD1 Directionally drill 1,56/1.66 at 2950 psi 17 k WOB, -3k surface wt. ROP 4-10, In shale. TF 160R Drilled to 10726. ROP slow in shale will take a look at bit. 02:00 - 04:00 2.00 DRILL P PROD1 POH. 04:00 - 04:40 0.67 DRILL P PROD1 Bit graded 1; 1.Replaced with Hycalog to try a different profile. Change MWD probe, 04:40 - 06:30 1,83 DRILL P PROD1 RIH to 9875'. 06:30 - 07:00 0.50 I DRILL P PROD1 Tie in. No correction required. 07:00 - 08:40 1.67 DRILL P PROD1 RIH to TD. - Stacked up at shale from 10,018 - 10,100 'MD, Orienting to get through shales. Multiple attempts with no flow and flowrate from 0.6 - 1.4 bpm. - Stacking up at shale from 10,600 - 10,700' MD. Orientation correct. Multiple attempts to get through (0.0 - 0.6 bpm). - Tag bottom. Motor work, PU to ensure free. PU at 42k (18k overpull). - Work back to bottom. No go, - Decision to weight up mud (mud swap). 08:40 - 09:15 0.58 DRILL P PROD1 Wiper trip to 10,200' MD for hole conditioning. -1.6 bpm, 3350 psi. - 26k PU; 13k SO. - Motor work at 10,580' RBIH. Could not get to TD, 09:15 - 10:00 0,75 DRILL P PROD1 Wiper trip to tubing tail to clean hole, - 1.5 bpm, 3000 psi. - Motor work at 10,280' MD. 10:00 - 12:00 2.00 DRILL P PROD1 RBIH from tubing tail. - Tag up at 9986' MD (at proper orientation), Attempt multiple pump speeds, no go. Shut pumps down, Run through. - Tag bottom at 10,715', moved slick through shale at 10,600' MD. - PU off bottom (sticky), work back down. Confirm TD. - Correct CTD to 10,726' MD at TD. 12:00 - 13:00 1.00 DRILL P PROD1 Attempt to drill ahead - Begin mud swap (9.1 ppg Flo Pro). New mud at bit at 12:30 hrs. - Packing off I sticky, tough getting started. 13:00 - 20:30 7.50 DRILL P PROD1 Drill ahead at 10,804' MD. - 25.5k PU; 11k SO - 1.6/1.7 bpm, 4300 psi with new mud. - 3750 psi free spin, Printed: 12/14/2004 8:22:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-28 02-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/17/2004 Rig Release: Rig Number: N1 Spud Date: 2/27/1990 End: 12/2/2004 13:00 - 20:30 7.50 DRILL P PROD1 - Orientation 95 RHS TF. -10-14kWOB - 1 - 50 fph Rap 20:30 - 21:45 1.25 DRILL P PROD1 Wiper to 10550. No problems. 21 :40 - 00:00 2.33 DRILL P PROD1 Directionally drill 1,6/1 ,7 bpm @4000 psi, 3650 psi = FS, Up Wt 25k, Dn Wt 12K, Surface wt -6K, Rap 8-33, Drill to 10899 12/3/2004 00:00 - 04:30 4.50 DRILL P PROD1 Directionally drill, 1,56/1.67 bpm @4080 psi, 3650 psi = FS, Up Wt 25k, Dn Wt 12K, Surface wt -6K, Rap 48. Drill to 8915 tvd still in shale. Only 20' below gas. Geo directed to drill back thru shale to look for a pay zone below shale. 04:30 - 06:45 2,25 DRILL P PROD1 Continue drilling shale, 1,58 I 1.66 bpm at 4180 psi. Drill to 11012'. 06:45 - 08:30 1,75 DRILL P PROD1 Wiper trip to window, - 27k PU; SO 12k - POOH clean. - RBIH. Tag at 10,000'. PU. RIH clean. - Tag at 10,600'. PU, RIH. - Stack up periodically on trip in, broke through, - Stack up at 10,995' MD, PU. RIH. Difficulty getting to TD. 08:30 - 09:45 1.25 DRILL P PROD1 Drill ahead to 11,030' at 90R (falling to 135R) -1.56/1.68 bpm, 4100 psi. - 3650 free spin, - 10 - 20k WOB. 09:45 - 10:00 0,25 DRILL P PROD1 Orient TF to 90R. 10:00 - 16:15 6.25 DRILL P PROD1 Drill ahead to 11,104' - 1.56 11.68 bpm, 4100 psi. - 3650 free spin, - 10 - 20k WOB. 16:15 - 17:00 0.75 DRILL P PROD1 Wiper trip to tubing tail. - POOH, ratty at 10,600' MD (motor work and 10k overpull). 17:00 - 17:20 0,33 DRILL P PROD1 Tie in, 0' correction. 17:20 - 18:00 0.67 DRILL P PROD1 RIH. - Motor work and stacking up at 10,100' MD (minor) - Motor work and stacking up at 10,600' MD, 10,730' MD. Work down to bottom varying pump rate and running speed. 18:00 - 22:30 4.50 DRILL P PROD1 Directionally drill 1.48 I 1.59 bpm at 3750 psi, Surface wt -9K,ROP 12. Drill to 11157' 22:30 - 00:00 1.50 DRILL P PROD1 Wiper to window, Overpulls & ,motor work, thru shales. 12/4/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Wiper to window. Set down 10603 top of shale, 10621, 10707, 10770.10880,10930,10953,10980,11015,11071,11106,& 11135 01 :00 - 01 :30 0.50 DRILL P PROD1 Orinet and work to bottom 01 :30 - 02:30 1.00 DRILL P PROD1 Attempt to drill can't slide. Poor hole conditions, Currently TVD at bit 8929. Targeting 8935, Un likely to get liner thru shale even if we could drill to planned TD. Discuss option with Cole Able. Running out of battery life, have to service SCR. Decided to POH repair SCR and change out MWD. Wait on orders. 02:30 - 05:00 2.50 DRILL P PROD1 POH. Over pulls 30K at 10780. 10744 Stuck, Slack off -6K. RIH 10750. POH. Over pulls @ 10730. POH, 05:00 - 05:45 0.75 DRILL P PROD1 LD BHA. 05:45 - 12:45 7.00 DRILL N WAIT PROD1 Waiting on orders. Mobilize Weatherford. NOTE: Printed: 12/14/2004 8:22:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-28 02-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/17/2004 Rig Release: Rig Number: N1 Spud Date: 2/27/1990 End: 12/412004 05:45 - 12:45 [ 7.00 DRILL N WAIT PROD1 - Close Swab - Working on SCR system. 12:45 - 14:00 I 1,25 DRILL C PROD1 PU Weatherford 2,5" aluminum billet and running tools. - Open swab, well on vac. 14:00 - 15:45 1.75 DRILL C PROD1 RIH pumping at 0.5 bpm, 1300 psi at 100 fpm. - Correct to flag at 8586.6' MD 115:45 - 16:30 - PU 27k; SO 18k 0,75 DRILL C PROD1 Set OH WS - Tag shales at 9977' MD cannot get any further. Confirm depth with ANC. - PU to drop 9/16" steel ball. - Pump ball down at 1.73 bpm, 3000 psi. Slow pumps at 35 bbls away to minimum rate at 0,25 bpm, 1300 psi. - PU to neutral wt at 9972' MD - Ball on seat at 35,3 bbls. - Saw bobble at 3200 psi. Did not look like a good ball shear, pressure did not bleed off. Bled off through choke. - Set down, confirm tag at 9977' MD 16:30 - 18:00 1.50 DRILL C PROD1 POOH. Billet did not set. 18:00 - 20:00 2,00 DRILL X DFAL PROD1 Review options with anchorage office and Weatherford. Decided to Open hole side track. 20:00 - 20:40 0,67 DRILL C PROD1 MU OH side track BHA. 20:40 - 22:45 2.08 DRILL C PROD1 RIH 22:45 . 23:00 0.25 DRILL C PROD1 Tie -in. Correction +8', 23:00 - 23:25 0.42 DRILL C PROD1 RIH to 10000'. Orient to 148L. 23:25 - 00:00 0.58 DRILL C PROD1 Trough from 9985 to 10,000 1.50/1.58 bpm at = 3475 psi.TF 148L, 12/5/2004 00:00 - 05:00 5,00 DRILL C PROD1 Backream to 9985 @ 50 fph , Trough 9985 to 10000 at 15/hr. Time drill 1 ftIhr. Drill to 10002. Orient 103L. drill 1.5 I 1.6 bpm @ 3450 psi. drill to 10005. Orient 25L Drill to 10020'. Orient 178R. Backream from 10008 to 9975. Orient to 165L. Dry tag at 10020 OK, 05:00 - 06:30 1.50 DRILL C PROD1 POH. 06:30 - 07:00 0.50 DRILL P PROD1 Change out bit to Hughes BC. 07:00 - 09:30 2,50 DRILL P PROD1 RIH. SHT at 4100' MD. Orient HS through whipstock. Orient 140 LOHS through ST. Tag bottom at 10,021'MD. 09:30 - 09:45 0.25 DRILL P PROD1 Orient 30L. 09:45 -11:15 1.50 DRILL P PROD1 Drill ahead to 10,057' MD. - PU 24k; SO 13k - Free spin 3350 - 1.5 I 1.6 bpm, 3600 psi. 11:15-11:45 0,50 DRILL P PROD1 Orient TF to 10L. 11 :45 - 14:30 2,75 DRILL P PROD1 Drill ahead to 10,134' MD, - PU 24k; SO 13k - Free spin 3600 -1.6/1.7 bpm, 3900 psi. 14:30 - 15:00 0.50 DRILL P PROD1 Orient TF to 45R. 15:00 - 15:45 0.75 DRILL P PROD1 Drill ahead to 10,170' MD. · PU 24k; SO 13k · Free spin 3600 · 1.6 11.7 bpm, 3900 psi. 15:45 - 16:25 0.67 DRILL P PROD1 Wiper trip to whipstock. · POOH. Motor work and bobble at 9987' MD. Printed: 12/14/2004 8:22:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-28 02-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/17/2004 Rig Release: Rig Number: N1 Spud Date: 2/27/1990 End: 12/512004 15:45 - 16:25 0,67 DRILL P PROD1 - RIH. Orient at OHST, - Orient to 60 R. 16:25 - 18:00 1.58 DRILL P PROD1 Drill ahead 10,259' MD - PU 24k; SO 13k - Free spin 3600 - 1.6 11.7 bpm, 4000 psi. 18:00 -18:15 0.25 DRILL P PROD1 Orient TF to 90 R. 18:15 -18:45 0.50 DRILL P PROD1 Drill ahead 10,270' MD - PU 24k; SO 13k - Free spin 3600 - 1.5 1.6 bpm, 3700 psi. - ROP 60 -WOB 18:45 - 21 :00 2.251 DRILL P PROD1 POH. for lateral drilling assembly. 21 :00 - 21 :30 0,50 DRILL P PROD1 Dial down motor angle to 1.1 and replace MWD probe. 21:30 - 23:15 1.75 DRILL P PROD1 Rih to 4100. Shallow hole test. OK. RIH to 9880' 23:15 - 23:30 0.25 DRILL P PROD1 Tie -in. Correct -3' 23:30 . 23:45 0.25 DRILL P PROD1 Orient 112L. Rlh thru OHST, 23:45 - 00:00 0,25 DRILL P PROD1 Directionally drill 1.55/1.62 bpm @4500 psi. 3675 spi = FS, ROP 110, GR 65 API 12/6/2004 00:00 - 07:45 7,75 DRILL P PROD1 Continue to directionally drill 1,55/1,62 bpm @4500 psi. 3675 spi = FS, ROP 10-60, Drill to 10380. 07:45 - 08:15 0.50 DRILL P PROD1 Orient to 90L, 08:15 - 09:45 1.50 DRILL P PROD1 Drill ahead to 10449' MD. . 1.6 I 1.7 4200 psi - Free spin 3750 psi - PU 28k; SO 11 k - 50 fph ROP. 09:45 - 10:30 0,75 DRILL P PROD1 Wiper trip to window, Orient 120L. 10:30 - 13:45 3,25 DRILL P PROD1 Drill ahead 10,600'MD - 1.6 11.74200 psi - Free spin 3750 psi - PU 28k; SO 11 k 13:45 - 15:00 1.25 DRILL P PROD1 Wiper trip to whipstock. Tie in to RA tag. 15:00 - 23:00 8,00 DRILL P PROD1 Drill ahead -1.6/1.74200 psi - Free spin 3750 psi - PU 28k; SO 11 k - Hit shale at 10662', to 10728 slow ROP. 6 - 13 23:00 - 00:00 1.00 DRILL P PROD1 Drill ahead - 1.47/1.62 4000 psi - Free spin 3700 psi - PU 26k; SO 13k . ROP. 30 12/7/2004 00:00 - 00:30 0,50 DRILL P PROD1 Drill to 10755. 00:30 - 01 :30 1,00 DRILL P PROD1 Wiper to 10050. No Problems. 01 :30 - 04:30 3.00 DRILL P PROD1 Drill ahead - 1.63/1.744000 psi - Free spin 3700 psi - PU 26k; SO 13k - ROP. 44 - 70 API from 10750 to 10891 04:30 - 05:45 1.25 DRILL P PROD1 Wiper to 10025 over pull 10272 over pull and stall @ 10050'. Printed: 12/14/2004 8:22:30 AM Legal Well Name: 02-28 Common Well Name: 02-28 Spud Date: 2/27/1990 Event Name: REENTER+COMPLETE Start: 11/17/2004 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 12/7/2004 04:30 - 05:45 I 1.25 DRILL P PROD1 Set dowm at 10066, NO GO, Orient high side. RIH min rate.NO GO. Stack out bounce thru. 05:45 - 11 :30 5.75 DRILL P PROD1 Drilling ahead to 10,944', fighting shales I 1.61 bpm 13850 psi I 28L I -3150 WOB 11 :30 - 11 :45 0.25 DRILL P PROD1 Orient TF to 90L. 11:45 - 14:35 2.83 DRILL P PROD1 .Drill ahead - 1.66 11,794000 psi - Free spin 3700 psi - PU 26k; SO 13k - ROP.3 - 160 API Break thru stringer @ 10959 to 10974. 14:35 - 18:00 3.42 DRILL P PROD1 .Drill ahead - 1.60 11.724000 psi - Free spin 3700 psi - PU 26k; SO 13k 18:00-21:151 - ROP slow still in shale, 3.25 DRILL P PROD1 Drilling lateral in 21 A shales, 1.6 I 1,6 bpm, 4100 - 4400 psi, I 60L, 92 deg incl, 10 fph, Drilled to 11,023', I 21:15 - 22:00 0.75 DRILL P PROD1 Wiper trip to window. Motor work at 10,060'. Hole looked good. 22:00 - 22: 15 0.25 DRILL P PROD1 Log GR tie-in with RA tag. Added 3 ft to CTD. 22:15 - 23:00 0.75 DRILL P PROD1 RIH. Lost weight at 10,060' and fell thru, RIH clean to bottom. 23:00 - 23:15 0.25 DRILL P PROD1 Orient TF to 80L. 23:15·00:00 0,75 DRILL P PROD1 Drilling lateral in 21 A shales, 1,6 I 1.6 bpm, 4000 - 4400 psi, 00:00 - 02:00 I 80L, 92 deg incl, 10 fph, Drilled to 11,030'. 12/8/2004 2,00 DRILL P PROD1 Drilling 21A lateral, 1.6 11.6 bpm, 3900 - 4300 psi, 73L, 92 deg, 20 fph, Looking for sand, Drilled to 11,060'. 02:00 - 03:15 1.25 DRILL P PROD1 Drilling 21 A lateral, 1.6 I 1.6 bpm, 3900 - 4300 psi, 73L, 93 deg, 100 fph, Drilled into sand at 11,080'. Drilled to 11,132' 03:15·03:30 0,25 DRILL P PROD1 Orient TF to 100L. 03:30 - 04:15 0.75 DRILL P PROD1 Drilling 21 A lateral, 1,6 I 1,6 bpm, 3900 - 4300 psi, 100L, 88 deg, 120 fph, Drilled to 11,200'. 04:15 - 05:40 1.42 DRILL P PROD1 Wiper trip to window, Clean hole up to 10340', overpull in shale. Rest of hole was clean. RIH, 05:40 - 06:15 0.58 DRILL P PROD1 Drilling 21 A lateral, 1.6 I 1,6 bpm, 3900 - 4300 psi, 80L, 90 deg, 130 fph, Drilled to 11,282', 06:15 - 06:30 0.25 DRILL P PROD1 Orient to 100L. 06:30 - 07:00 0,50 DRILL P PROD1 Drilling 21A lateral, 1.6 11,6 bpm, 3900 - 4300 psi, 80L, 90 deg, 130 fph, Drilled to 11,350 07:00 - 08:30 1.50 DRILL P PROD1 Wiper to 10080. Clean trip all the way. 08:30 - 08:40 0.17 DRILL P PROD1 Orient 100L 08:40 - 10:00 1.33 DRILL P PROD1 Drilling 21 A lateral, 1,6 I 1.6 bpm, 3900 - 4600 psi, 80 fph, TF=61 L Drilled to 11,425 10:00 - 10:15 0.25 DRILL P PROD1 Orient 68R 10:15 - 11 :15 1.00 DRILL P PROD1 Drilling 21 A lateral, 1.6 I 1.6 bpm, 3900 - 4600 psi, 80 fph, TF=61 L Drilled to 11,500. Swap to new mud. 11 :15 - 13:00 1.75 DRILL P PROD1 Wiper 10050. Set down 11,100 one time, 13:00 - 16:00 3.00 DRILL P PROD1 Drilling 21 A lateral, 1,6 I 1,6 bpm, 3600 - 4000 psi, 80 fph, TF=164R. 11530 back in shale, Drill to 11591. Ran out of battery life on MWD tools. Anticipated battery life 60 hours actual 67 hours. Printed: 12/14/2004 8:22:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-28 02-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/17/2004 Rig Release: Rig Number: N1 Spud Date: 2/27/1990 End: POH. Layout BHA. Bit still in good condition, no chipped cutters, 2 ports plugged with rubber 19:15 - 19:30 0,25 PROD1 Function test BOPE against 2" test joint. All rams closedlopened OK. Send test form to AOGCC. 19:30 - 19:45 0,25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for M/U MWD BHA. 19:45 - 20:30 0,75 DRILL P PROD1 M/U MWD lateral BHA with new 1,1 deg motor and HC 3.0" BC re-run bit #7. M/U new MWD probe, new orienter and new Baker MHA. OAL = 58,98'. 20:30 - 22:30 2.00 DRILL P PROD1 RIH. SHT tools and orienter, OK, RIH. 22:30 - 23:00 0.50 DRILL P PROD1 Log GR tie-in at RA tag. -3 ft CTD. 23:00 - 00:00 1.00 DRILL P PROD1 RIH. Set down at 10,060', RIH, set down at 10990',11010' and 11060'. RIH to bottom and tag at 11,591'. 12/9/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Tag bottom at 11,591'. Back ream up to 10800'. Ream down to bottom. 01 :00 - 01 :30 0.50 DRILL P PROD1 Orient TF to 90R. 01 :30 - 02:00 0.50 DRILL P PROD1 Drilling Z1A lateral, Stacking weight, slow drilling, not getting motor work, Drilled to 11,595'. 02:00 - 03:45 1,75 DRILL P PROD1 Wiper trip to 10,100' to clean hole and allow better drilling. Added 1% LubeTex to system. 4% total. Reamed shales at 11000', Wiper up to 10100'. RIH. Went thru shales at 11000' OK. RIH to bottom with better weight. 03:45 - 05:00 1.25 DRILL P PROD1 Drilling Z1 A lateral, 1.5 I 1.5 bpm, 3100 - 4000 psi, 90R, 88 deg incl, Drilling clean sand. Drilled to 11,614', 05:00 - 06:00 1.00 DRILL P PROD1 Drilling Z1A lateral, 1.5 11.5 bpm, 3100 - 4000 psi, 95L, 89 deg incl, Drilling clean sand. Stacking weight. Drilled to 11,642'. 06:00 - 08:45 2.75 DRILL P PROD1 Drilling Z1A lateral, 1.6 11.6 bpm, 3370 psi, 142R, 88 deg incl, Drilling clean sand, Stacking weight. Drilled to 11675. Run into bottom and drill off with diminishing results. 08:45 - 10:30 1.75 DRILL P PROD1 Wiper to 10080'. Ratty 10980 -11170 on trip back in hole. 10:30 - 14:00 3.50 DRILL P PROD1 Drilling Z1A lateral, 1.6 11,6 bpm, 3370 psi, 158R, 88 deg incl, 11650 Drilling shales. Stacking weight. Drilled to 11686 Orient 100L. Continue to drill stacking. Increase lubricants to max allowable. Drill to 11723. 14:00 - 15:00 1.00 DRILL P PROD1 Orient HS. Drilling Z1A lateral, 1,6 11.6 bpm, 3600 psi" 89 deg incl, Drilling shale, Stacking weight. Drilled to 11724. Called TD. 15:00 - 16:20 1.33 DRILL P PROD1 Wiper to window, Ratty 11100 to 10880. Make double pass. POH to 9875'. 16:20 - 16:45 0.42 DRILL P PROD1 Tie - in. RA tag at 9835', Correction = +7.5'. 16:45 - 17:30 0.75 DRILL P PROD1 Wiper to TD. Set down at 10930 & 10962. Tag at 11728. 17:30 - 20:30 3.00 DRILL P PROD1 POH. Flag CT at 8900' and 7000' EOP. POH. Circ to surface. 20:30 - 22:00 1,50 DRILL P PROD1 Layout MWD BHA. Bit graded at [ 0,1,1 ]. 22:00 - 22:30 0,50 CASE P RUNPRD Circ. Baker Dart to check coil volume and clearance. Dart landed at 39.9 bbls. 22:30 - 22:45 0,25 CASE P RUNPRD SAFETY MEETING, Review procedure, hazards and mitigation for running 2-3/8" liner. 22:45 - 00:00 1,25 CASE P RUNPRD Run 2-3/8", 4.70#, L-80, STL liner with Baker Float equipment. Run 45 joints. Drift each connection after make-up with 1.875" Baker drift on 1" CSH. Fill liner with water. 12/10/2004 00:00 - 01 :00 1.00 CASE P RUNPRD Run 2-3/8", 4,70#, L-80, STL Liner, Stop at 45 joints and fill Printed: 12/14/2004 8:22:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-28 02-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/17/2004 Rig Release: Rig Number: N1 Spud Date: 2/27/1990 End: 12/10/2004 00:00 - 01 :00 1.00 CASE P RUNPRD with water 01 :00 - 02:15 1.25 CASE P RUNPRD Run 2-3/8",4,70#, L-80, STL Liner. Run total of 88 jts, Drift each connection after M/U with 1.875" Baker drift. M/U 10' and 3' pups for spacing, 02:15·02:50 0.581 CASE P RUNPRD M/U Baker Deployment Sleeve and pup with LWP. OAL of Liner = 2,744.69 ft. M/U Baker CTLRT, BHA OAL '" 2746,89', 02:50 - 04:15 1.42 CASE P RUNPRD RIH with 2-3/8" liner on coil. Circ. FloPro at 0.25 bpm, 1400 psi. RIH at 90 fpm, Correct depth at flag to 9747', [-7 ft]. Up Wt = 28K, Dwn Wt = 15,5K, 04:15 - 05:00 0.75 CASE P RUNPRD Ran thru window with no weight loss. RIH at 50 fpm, 0.20 bpm, 1500 psi. Sat down at 10040',10060' and 10150', RIH OK and sat down in shales at 11,030', 11050', 11055', 11060' and 11080'. 05:00 - 06:00 1,00 CASE P RUNPRD RIH with liner at 50 fpm, 0.2 bpm at 1650 psi. Sat down at 11290'. RIH OK and sat down at 11450', 11460', 11600', 11700' and 11705', Up wt = 32K, Dwn wt '" 8K, Sat down at 11710', 11715', 11716', and 11721'. Sat down 6 times at 11,721'. Liner is landed at TD or as deep as it will go, TD = 11,728 ft. 06:00 - 07: 15 1.25 CASE P RUNPRD Drop 5/8" AI. ball and kick out with 1300 psi..42 bpm @ 1825 psi .On seat 33.5 bbl. shear at 4080 psi. PU 20K versis 34K. Slack of 5K, 07:15 - 09:30 2,25 CASE P RUNPRD Displace well to 9.2ppg brine. 1.4 bpm @ 3230 psi. initially 1:1 returns, reducing to 70% returns. Prior to brine turning the corner. 50% returns as brine turns corner. 09:30 - 11 :45 2.25 CEMT X RUNPRD Wait on arrival of cementers, 11 :45 - 12:45 I 1.00 CEMT C RUNPRD RU cementers 12:45 - 13:00 I 0.25 CEMT C RUNPRD PJSM. with all personnel concerning cementing operation. 13:00 - 14:30 1.50 CEMT C RUNPRD Batch mix 16 bbl15.8 'G' cement Cement to weight 13:10. Flush and PT liners to 4000 psi. Pump 16 bbl @ 1.53/1.25 bpm at 3800psi. Close inner reel valve and clear lines with Bio. Load and launch CTWP with 300 psi. Chase with 30 bbl; 9.2 ppg bio 1,44 I 1.01 bpm at 3600 psi.Shear plug with 4050 psi. Continue to displace LWP1.38 11.04 bpm @ 2400 psi. Bump at 9.5 bbl ( calculated 10.4bbl), PT 2800 psi. Bleed off floats held. Repressure to 3000 straight lined OK. 1,2 bbls cement lost to formation. 14:30 - 16:30 2.00 CEMT P RUNPRD POH LD running tools 16:30 - 17:30 1.00 EVAL X LOWER1 Wait on Loggers, SWS had 2 other memory logging jobs going. 17:30 - 19:00 1.50 EVAL C LOWER1 Rig up SWS memory logging tools in rig pipe shed. P/U tools to rig floor. 19:00 - 19:15 0.25 EVAL C LOWER1 SAFETY MEETING, Review procedure, hazards and mitigation for picking up source for CNUGR memory logging tools. 19:15 - 20:00 0.75 EVAL C LOWER1 Pick up SWS memory CNUGR/CCllogging tools and SWS ported sub, Baker circ sub, Baker hyd discon and XO to 1" CSH. Printed: 12/14/2004 8:22:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-28 02-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/17/2004 Rig Release: Rig Number: N1 Spud Date: 2/27/1990 End: 12/10/2004 20:00 - 22:30 2,50 EVAL C LOWER1 RIH with 48 stds of 1" CSH, M/U Baker Hyd disc, checks, I swivel and CTC, I BHA OAL = 3011 '. 122:30 - 00:00 1,50 EVAL C LOWER1 RIH with SWS Memory logging tools, circ at 0.7 bpm, 1800 psi. RIH to 8800', 12/11/2004 00:00 - 01 :50 1.83 EVAL C LOWER1 Stop at 8800'. Log down at 30 fpm with SWS Memory CNUGR/CCL tools. Circ at 0.7 bpm, 2400 psi. RIH clean and Tagged PBTD of 11,691' at 11,687' CTD. 01 :50 - 02:45 0,92 EVAL C LOWER1 Log out at 60 fpm while laying in a 14 bbl New FloPro perf pill. 02:45 - 04:15 1.50 EVAL C LOWER1 POH while circ at 1.0 bpm, 3000 psi. 04: 15 - 06:30 2,25 EVAL C LOWER1 Stand back 27 STDS of 1" CSH. Layout 42 singles. 06:30 - 07:30 1,00 EVAL C LOWER1 PJSM for laying down logging tools. 07:30 - 07:45 0.25 EVAL C LOWER1 LD logging tools. 07:45 - 08:50 1,08 EVAL P LOWER1 RIH with 50 stands of 1-1/4" CSH. 08:50 - 11 :30 2.67 EVAL P LOWER1 POH LD 1-114" CSH. 11:30 -15:30 I 4,00 EVAL C LOWER1 WOC. UCA 1825psi look like it would take 2.5 additional hours to reach 2000 psi. OK from Anchorage to proceed. 15:30 - 16:00 0.50 LOWER1 Test liner and lap to 1700 spi with 9.2 ppd brine. (= 2000 psi with 8,5 ppg) Hold inner annulus 500 bleed to 250 psi during test. Lap tested OK. Lost 92 psi in 30 minutes. 16:00 - 16:30 0,50 LOWER1 PJSM 16:30 - 18:30 2.00 LOWER1 PU perforating assy 1325.6' consisting of 860', 1.56 ", 6SPF to perforate 10350 - 10660 1 0750 - 10880 11080 - 11425 11575 - 11650 18:30 - 20:15 1.75 PERFO C LOWER1 M/U SWS firing head, Baker Hyd Discon and XO to 1" CSH workstring. RIH with 25 STDS of 1" CSH, M/U Baker XO, Hyd Discon, check valves and swivel to SWS CTC. BHA OAL = 2,884', 20:15 - 23:00 2.75 PERFO C LOWER1 RIH with SWS 1.56" Perforating BHA. Circ. at surface before RIH. 0.30 bpm, 300 psi. RIH clean thru top of liner and tagged PBTD at 11,684', corrected [+ 8 ft CTD] to PBTD of 11,692'. Pulled guns 300 ft up hole just to ensure no overpull problems. 28K Up Wt. 16K Own WI. RIH and tag TD again, Pick up on depth at 11,692'. Pump 12 bbls of New FloPro ahead of 518" ball. Insert 5/8" AL Ball. Displace ball with 5 bbls FloPro followed by KCL water. 23:00 - 00:00 1.00 PERFO C LOWER1 Position bottom shot at 11,655 ft and displace ball at 1.0 bpm, 2500 psi. Slow down at 30 bbls displacement to 0.75 bpm, 1200 psi. Ball on seat at 39.9 bbls. Pull at 5 fpm and fired guns on depth with bottom shot at 11,650'. Fired at 3200 psi, Good indication guns fired with shot detector. POH at 60 fpm, circ at 1.0 bpm, 2600 psi while holding 400 psi WHP with choke. Up wt went to 32K after guns fired and fell back to 25K while POH. Monitor in and out Micromotion meters, not swabbing well. Printed: 12/14/2004 8:22:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-28 02-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/17/2004 Rig Release: Rig Number: N1 Spud Date: 2/27/1990 End: 00:50 - 02:00 02:00 - 03: 15 03:15 - 03:30 03:30 - 06:00 06:00 - 08:30 08:30 - 10:15 10:15 - 10:30 10:30 - 11: 10 11:10-13:30 13:30 - 15:00 1,00 0.83 1,17 1,25 2,50 WHSUR P 1.75 WHSUR P 0.25 WHSUR P 0.67 RIGD P 2,33 RIGD P 1 RIGD P LOWER1 LOWER1 LOWER1 LOWER1 POST POST POST POST POST POST No overpulls while pulling guns out of 2-3/8" Liner. POH with perf guns to 8800 ft. No overpulls while pulling out of 2-3/8" liner. Stop at 8800' and circ, full returns, Flow check OK. POH, circ. 1.3 bpm, 2900 psi. Flow check with Baker tools at surface. OK. Layout 50 jts of 1" CSH for rig move. SAFETY MEETING, Review procedure, hazards and mitigation for laying out fired perf guns and blanks. Layout fired perf guns, all shots fired so far. 1,326' of guns and blanks, Clear floor MU nozzle. RIH to 2500 . and freeze protect with 35 bbl methanol. POH, Close master PJSM for N2 blow down. Blow down reel with N2 with 24300 cuft. Pull back coil and secure coil. RD injector and gooseneck. Nipple down the BOP, Change out choke hose. NU tree cap and test. RELEASED RIG AT 1500 HRS, 12/12/2004. RIG ACCEPT TO RIG RELEASE WAS 15 DAYS 5-1/2 HOURS. WELL PLAN WAS 17.3 DAYS Printed: 12/14/2004 8:22:30 AM . . svy4462 Survey Ref: Halliburton Sperry-Sun North Slope Alaska BPXA 02-28A Job No. AKMW3410649, Surveyed: 9 December, 2004 Survey Report 16 December, 2004 Your Ref: API 500292201201 Surface Coordinates: 5950926.20 N, 687529.59 E (70016'14.7764" N, 148028' 59.6855" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 62.00ft above Mean Sea Level spe............'J-5UI! DFUL.L-INC!i SE!AVIc:.eS A Halliburton Company Halliburton Sperry-Sun Survey Report for 02-28A Your Ref: API 500292201201 Job No. AKMW3410649, Surveyed: 9 December, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9982,89 50,120 325,650 8846.79 8908,79 1757,10 N 2836,85 W 5952612.07 N 684649.84 E 2564,70 Tie On Point 9990.00 50,850 327.520 8851.31 8913.31 1761.68 N 2839.87 W 5952616.58 N 684646.71 E 22.739 2567,05 Window Point 10029.55 51,150 314.590 8876.27 8938.27 1785.49 N 2859.12 W 5952639.90 N 684626.87 E 25.397 2582,80 10060.26 59.150 312.830 8893,80 8955.80 1802.88 N 2877.33 W 5952656,82 N 684608,23 E 26.470 2598.42 10095.93 67.850 313,710 8909,70 8971.70 1824,74 N 2900,55 W 5952678,11 N 684584.48 E 24.490 2618.37 . 10131.03 77 ,080 314.590 8920.27 8982.27 1848.04 N 2924.53 W 5952700.79 N 684559.92 E 26.404 2638,87 10160.99 84.370 319.330 8925.10 8987.10 1869.63 N 2944.68 W 5952721.88 N 684539.23 E 28.905 2655.82 10194.21 91.140 326.890 8926.40 8988.40 1896.15 N 2964.58 W 5952747.89 N 684518.68 E 30,526 2671.84 10226.95 92.200 337.090 8925.44 8987.44 1925.00 N 2979.93 W 5952776,36 N 684502,62 E 31.309 2683.02 10255,77 90.260 341 .480 8924,82 8986,82 1951,95 N 2990,12 W 5952803.04 N 684491.76 E 16.650 2689,36 10293.56 89.910 349.390 8924.77 8986.77 1988.49 N 2999.61 W 5952839.34 N 684481.36 E 20,952 2693.68 10322.58 89.120 351.330 8925.01 8987.01 2017.10 N 3004.47 W 5952867,81 N 684475,79 E 7.218 2694.51 10356.45 87,100 346,760 8926,13 8988.13 2050,33 N 3010,90 W 5952900,87 N 684468,53 E 14.745 2696.25 10389.33 89,820 342,360 8927.01 8989,01 2082,00 N 3019,65 W 5952932.31 N 684459.00 E 15.727 2700,51 10429.53 89.470 336.740 8927.26 8989.26 2119.65 N 3033.69 W 5952969,60 N 684444.03 E 14,007 2709,17 10468.58 87.450 332.690 8928,31 8990.31 2154,93 N 3050,36 W 5953004.46 N 684426.48 E 11 .586 2720.76 10514,58 86,220 326.540 8930.86 8992,86 2194.54 N 3073.58 W 5953043.47 N 684402.29 E 13.614 2738,25 10554.95 86.750 320.210 8933.33 8995.33 2226.86 N 3097.60 W 5953075,18 N 684377.46 E 15,705 2757.54 10594.47 89.380 316,170 8934,67 8996,67 2256,29 N 3123,93 W 5953103.95 N 684350.41 E 12.192 2779.51 10628.63 91.140 310.190 8934.51 8996.51 2279.65 N 3148.83 W 5953126.69 N 684324.94 E 18.247 2800,92 10661,29 92.110 305,100 8933,59 8995.59 2299,58 N 3174,67 W 5953145,97 N 684298.61 E 15.859 2823.73 . 10692.43 91 .410 298.770 8932.63 8994,63 2316.04 N 3201.07 W 5953161.76 N 684271.81 E 20.442 2847,59 10727.71 93.250 294.550 8931.19 8993.19 2331.85 N 3232.56 W 5953176.79 N 684239.93 E 13,039 2876,57 10755,79 95.450 292,970 8929.06 8991.06 2343.13 N 3258.19 W 5953187.42 N 684214,03 E 9.636 2900.38 10787,65 93,510 288.400 8926.57 8988,57 2354,35 N 3287.89 W 5953197.89 N 684184.06 E 15.542 2928.23 10822.46 90.790 283.120 8925.27 8987.27 2363.79 N 3321.36 W 5953206,50 N 684150.37 E 17,052 2960.06 10855.35 89,910 276,270 8925.07 8987.07 2369,33 N 3353,76 W 5953211,23 N 684117,84 E 20.998 2991.37 10891.82 89.120 271.700 8925.38 8987.38 2371.86 N 3390.13 W 5953212.85 N 684081.42 E 12.716 3027.03 10925.90 90.000 268,180 8925.64 8987.64 2371.82 N 3424.20 W 5953211,97 N 684047.36 E 10.646 3060,78 10960.84 92.280 263.610 8924.94 8986.94 2369.32 N 3459.03 W 5953208.60 N 684012.60 E 14.614 3095,62 10990.33 92.810 260.450 8923.63 8985.63 2365.24 N 3488.20 W 5953203.79 N 683983.54 E 10,855 3125.08 11021,28 91.850 255,530 8922,37 8984.37 2358.81 N 3518.44 W 5953196,61 N 683953.47 E 16.183 3155.92 11054.58 92,110 250,600 8921.22 8983,22 2349,12 N 3550,27 W 5953186.13 N 683921.89 E 14.817 3188.78 11094.45 92.640 247.090 8919.57 8981.57 2334.74 N 3587.41 W 5953170.83 N 683885.12 E 8.896 3227.57 11138,32 92.010 240,900 8917,79 8979.79 2315.53 N 3626,79 W 5953150,65 N 683846,23 E 14.171 3269.23 16 December, 2004 - 18:50 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for 02-28A Your Ref: API 500292201201 Job No. AKMW3410649, Surveyed: 9 December, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11169,23 87.800 234.670 8917.84 8979.84 2299.07 N 3652.92 W 5953133.53 N 683820.52 E 24.322 3297.40 11211.42 89.380 228.450 8918.88 8980.88 2272,86 N 3685.94 W 5953106.51 N 683788.16 E 15.206 3333.75 11265,33 91.230 221.420 8918.59 8980.59 2234,72 N 3723.99 W 5953067.44 N 683751.07 E 13.483 3376,74 11328,37 90.970 215.100 8917.38 8979.38 2185,26 N 3763.00 W 5953017.02 N 683713,31 E 10.032 3422,25 11373,19 89.030 207,360 8917.38 8979.38 2146,96 N 3786.22 W 5952978.16 N 683691.05 E 17.802 3450,57 . 11413.03 90.090 197.870 8917.69 8979,69 2110,23 N 3801.52 W 5952941 .05 N 683676.67 E 23.967 3470,84 11457.65 93.870 198.750 8916.14 8978.14 2067,90 N 3815.53 W 5952898.39 N 683663.72 E 8.698 3490.60 11517.86 91.140 205.430 8913,51 8975,51 2012,20 N 3838.14 W 5952842,14 N 683642,51 E 11 ,974 3520.74 11564.18 87.540 212.990 8914,04 8976,04 1971,81 N 3860.72 W 5952801,20 N 683620,94 E 18,074 3548.72 11592.49 87.360 218.960 8915,31 8977,31 1948,93 N 3877.33 W 5952777 ,92 N 683604.91 E 21.077 3568.35 11630.56 88.240 215.620 8916,77 8978,77 1918,67N 3900,37 W 5952747,09 N 683582,62 E 9.066 3595.38 11654.24 88.420 215.800 8917.46 8979.46 1899.45 N 3914,19 W 5952727,53 N 683569,29 E 1.075 3611.74 11686.41 86.660 218.080 8918,84 8980,84 1873,77 N 3933,50 W 5952701,38 N 683550,62 E 8.948 3634.44 11709.85 90.000 219.310 8919,52 8981,52 1855.48 N 3948.14 W 5952682.73 N 683536.44 E 15,184 3651 .49 11728.00 90.000 219.310 8919.52 8981,52 1841 .44 N 3959,64 W 5952668.41 N 683525,29 E 0.000 3664.83 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North, Vertical depths are relative to Well Reference, Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4, The Dogleg Severity is in Degrees per 100 feet (US Survey), Vertical Section is from Well Reference and calculated along an Azimuth of 262,000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11728.00ft., The Bottom Hole Displacement is 4366.88ft., in the Direction of 294,941 ° (True). . 16 December, 2004 - 18:50 Page 3 of 4 Dril/Quest 3.03.06.006 Halliburton Sperry-Sun Survey Report for 02-28A Your Ref: API 500292201201 Job No. AKMW3410649, Surveyed: 9 December, 2004 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9982.89 9990.00 11728,00 8908.79 8913,31 8981.52 1757,10 N 1761.68 N 1841 .44 N 2836.85 W 2839.87 W 3959.64 W Tie On Point Window Point Projected Survey . Survey tool program for 02-28A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9807.50 0.00 9807.50 8773.88 11728,00 8773.88 BP High Accuracy Gyro - GCT-MS (02-28) 8981,52 MWD Magnetic (02-28APB1) . 16 December, 2004 - 18:50 Page 4 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun North Slope Alaska BPXA 02-28APB1 . Job No. AKMW3410649, Surveyed: 4 December, 2004 Survey Report 16 December, 2004 Your Ref: API 500292201270 Surface Coordinates: 5950926.20 N, 687529.59 E (70016'14.7764" N, 148028' 59.6855" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Kelly Bushing Elevation: 62.00ft above Mean Sea Level SpE!í'í'Y-5UI'l DRILLING SERVIC:ES A Halliburton Company Survey Ref: svy4461 Halliburton Sperry-Sun Survey Report for 02-28APB1 Your Ref: API 500292201270 Job No. AKMW3410649, Surveyed: 4 December, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9807.50 29.550 296.890 8711.88 8773.88 1688,01 N 2753,04 W 5952545,09 N 684735.34 E -2837.62 Tie On Point MWD Magnetic 9832,00 29.330 297.050 8733,21 8795.21 1693.47 N 2763,78 W 5952550,28 N 684724.48 E 0,954 -2848.62 Window Point 9856.15 32,340 301.610 8753,95 8815.95 1699.55 N 2774,55 W 5952556,09 N 684713,55 E 15.773 -2859.69 9889.64 38.140 306.560 8781,30 8843.30 1710.41 N 2790,50 W 5952566,55 N 684697,34 E 19.293 -2876.19 . 9922.37 44.230 310.350 8805.92 8867.92 1723.84 N 2807,34 W 5952579,56 N 684680,17 E 20.102 -2893.71 9951.67 47.810 318.240 8826,28 8888.28 1738.57 N 2822,37 W 5952593.91 N 684664,77 E 22.891 -2909.49 9982.89 50,120 325.650 8846,79 8908.79 1757.10 N 2836.85 W 5952612,07 N 684649,84 E 19.363 -2924.92 10013.40 53.440 333.400 8865,68 8927.68 1777.75 N 2848,95 W 5952632.41 N 684637,22 E 22.718 -2938.09 10048.60 58,010 339.370 8885.51 8947.51 1804.39 N 2860.56 W 5952658.76 N 684624,96 E 19.096 -2951.07 10077.70 63.810 343.770 8899,66 8961.66 1828.51 N 2868,56 W 5952682,66 N 684616,36 E 23.907 -2960.33 10111.30 69,710 345.990 8912,91 8974.91 1858.30 N 2876.60 W 5952712.25 N 684607,58 E 18.578 -2969.91 10140.40 75,760 345.000 8921.55 8983.55 1885.19 N 2883.56 W 5952738.95 N 684599,95 E 21.042 -2978.27 10174.00 82.620 349.220 8927,85 8989.85 1917.34N 2890,90 W 5952770,91 N 684591,81 E 23.850 -2987.29 10208,30 86,570 355.190 8931.08 8993.08 1951.15 N 2895,53 W 5952804,59 N 684586,35 E 20.803 -2993.67 10238,80 88.150 2.220 8932.49 8994,49 1981.59 N 2896,21 W 5952835,01 N 684584,90 E 23.600 -2995.95 10275,70 88.770 9.960 8933.48 8995.48 2018.24 N 2892,30 W 5952871,74 N 684587,90 E 21.035 -2993.97 10312,20 87.890 20.150 8934.55 8996,55 2053.42 N 2882,84 W 5952907.15 N 684596.48 E 28.010 -2986,36 10346.10 91.050 30.530 8934.86 8996,86 2084,01 N 2868.35 W 5952938.10 N 684610.20 E 32.002 -2973.49 10380.80 90.930 35.620 8934.26 8996,26 2113,08 N 2849.42 W 5952967.62 N 684628.40 E 14.670 -2956,11 10408.00 92,110 38.960 8933.54 8995.54 2134.71 N 2832.95 W 5952989.66 N 684644.33 E 13,019 -2940.79 10441.80 93,780 44.940 8931.80 8993.80 2159.80 N 2810.40 W 5953015.30 N 684666.25 E 18,346 -2919.58 . 10470.40 92,990 49.690 8930,11 8992.11 2179.15 N 2789.42 W 5953035.17 N 684686.74 E 16.808 -2899.64 10500.10 91,930 54.780 8928,84 8990.84 2197.31 N 2765.97 W 5953053.91 N 684709.73 E 17.490 -2877.18 10532.00 93,690 59.180 8927,27 8989.27 2214.67 N 2739.26 W 5953071.93 N 684736.00 E 14.840 -2851.42 10558.10 92.900 63,750 8925,77 8987.77 2227.12 N 2716,38 W 5953084,94 N 684758,56 E 17.741 -2829.21 10594,60 90.180 69,900 8924.79 8986.79 2241.47 N 2682,85 W 5953100,12 N 684791,72 E 18.417 -2796.49 10630.70 90.000 71 .480 8924.73 8986,73 2253.40 N 2648.79 W 5953112,90 N 684825.48 E 4.405 -2763.09 10663.80 89.300 77.990 8924.93 8986,93 2262,11 N 2616,87 W 5953122.41 N 684857.17 E 19.781 -2731,67 10695.30 89.030 83.080 8925,39 8987.39 2267.29 N 2585.81 W 5953128.36 N 684888.09 E 16,180 -2700.93 10722.00 89.380 88.530 8925,76 8987.76 2269.24 N 2559.20 W 5953130.97 N 684914.64 E 20.452 -2674.45 10752.00 92,200 92.930 8925.35 8987,35 2268,86 N 2529.21 W 5953131.34 N 684944.63 E 17.418 -2644.49 10781.10 92.900 96.790 8924.06 8986.06 2266.40 N 2500.25 W 5953129.60 N 684973.64 E 13.468 -2615.44 10812.20 92,640 102.240 8922.55 8984.55 2261,27 N 2469.63 W 5953125.23 N 685004.39 E 17,524 -2584.59 10844.30 91,930 106.640 8921 ,27 8983.27 2253.27 N 2438.57 W 5953118.01 N 685035,63 E 13.874 -2553.16 10876.20 93.950 111 .560 8919,63 8981.63 2242.85 N 2408.48 W 5953108.34 N 685065,97 E 16,653 -2522.56 16 December, 2004 - 18:49 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for 02-28APB1 Your Ref: API 500292201270 Job No. AKMW3410649, Surveyed: 4 December, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10909.90 93.340 116,660 8917.49 8979.49 2229.12 N 2377. 79 W 5953095,38 N 685096.99 E 15.211 -2491.20 10942,50 91.670 119,650 8916,06 8978.06 2213.75 N 2349.08 W 5953080,73 N 685126.08 E 10.497 -2461.72 10974,20 87.890 122,280 8916.19 8978,19 2197.44N 2321.91 W 5953065,11 N 685153.65 E 14.526 -2433.73 10995,80 86.480 125,620 8917,25 8979,25 2185.40 N 2304.02 W 5953053,51 N 685171.84 E 16,767 -2415.23 11028.40 84.730 131,070 8919.75 8981,75 2165.24 N 2278.53 W 5953034.00 N 685197.82 E 17,511 -2388.73 . 11064.40 85.250 135,820 8922.89 8984,89 2140.59 N 2252.50 W 5953010.00 N 685224.45 E 13,223 -2361.45 11099,50 86.040 142.320 8925.56 8987,56 2114.16N 2229.59 W 5952984.15 N 685248.02 E 18,602 -2337.18 11128.40 86.660 146,370 8927.40 8989.40 2090.73 N 2212,78 W 5952961.15 N 685265.40 E 14,149 -2319.17 11143,10 85.520 148.830 8928.40 8990,40 2078.35 N 2204.92 W 5952948.96 N 685273.57 E 18.409 -2310.67 11157,00 85.520 148.830 8929.49 8991.49 2066.49 N 2197,75 W 5952937.29 N 685281.03 E 0.000 -2302.89 Projected Survey All data is in Feet (US Survey) unless otherwise stated, Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 93,000° (True), Based upon Minimum Curvature type calculations, at a Measured Depth of 11157,OOft., The Bottom Hole Displacement is 3016,70ft., in the Direction of 313.237° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) . Comment 9807,50 9832.00 11157.00 8773.88 8795,21 8991.49 1688,01 N 1693.47 N 2066.49 N 2753,04 W 2763,78 W 2197,75 W Tie On Point Window Point Projected Survey 16 December, 2004 - 18:49 Page 3 of 4 DríllQuest 3.03.06.006 North Slope Alaska Survey tool program for D2-28APB1 F YO m Measured Vertical Depth Depth (ft) (ft) 0,00 9807,50 0.00 8773.88 To Measured Vertical Depth Depth (ft) (ft) 9807.50 11157,00 8773.88 8991.49 Halliburton Sperry-Sun Survey Report for 02-28APB1 Your Ref: API 500292201270 Job No. AKMW3410649, Surveyed: 4 December, 2004 BPXA Survey Tool Description BP High Accuracy Gyro - GCT-MS (02-28) MWD Magnetic (02-28APB1) . . 16 December, 2004 - 18:49 Dril/Quest 3.03.06.006 Page 4 of 4 ......lAx 50'. IAGELSQZ. PSI; MAX OAP ;:: WAIVER)...... DON'T RUN LGLV's, IA W/BRlNE OVERCRET lEAK. Minimum ID = 1.92" @ 2-3/8" STl PIN ID 3-1/2" TBG-PC, 9.3#, L-80, .0087 bpf, ID:;: 2.992" 9028' PERFORA TION SUMMARY REF LOG: SWS MEMORY CNLlGRlCCL OF 12/11/04 ANGLE AT TOP ÆRF: 87 DEG @ 10,350' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1,56" 6 10350 - 10660 1.56" 6 10750 - 10880 1.56" 6 11080 - 11425 1.56" 6 11575 -11650 COMMENTS ORIGINAL COMPLETION CORRECT!ONS PRUDHOE SAY UNrT SEC 3, T1 . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 2-28A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,982.89' MD 9,990.00' MD 11,728.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.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 Date ~ 7 ¡o-l'VL ~ \- Signed - ~/) I , ILl / / j ./ ,// Q IJ ' /~~. l;' I ' Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 27 -Dec-04 ~G '--1- f ~.~( . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 2-28A PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,807.50' MD 9,832.00' MD 11,157.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.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 Date ) ? II /1f}~JJJ( S-- Signed )/.1 I. J, ¿2JJL' .' /J t- t ¡ J. . v !'Y-t-trv-A ! '. ¡ f 27 -Dec-04 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) /~c¿ ~.Óv{-+~ bp . . ... ,"'.'11. -....~ ~ ~..- .,~ ·'1'" ". Terrie Hubble Technical Assistant Drilling & Wells BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 10, 2005 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Reference: Permits to Drill, 204-164 & 204-165 ("'~ c:.\\fç: 0\ R £,,,,,;1 r.: \ ,~ "":. '1 Í\ \1 '1 \. I \)l)·' '/)\\\1 ' J,~\. Þ.\~'$ÿ,(!. Direct: (907) 564·4628 hubbletl@bp.com To Whom It May Concern: Your guidance is requested in the following matter. Wells 02-28A (204-164) and 02-28AL 1 (204-165) were permitted and approved to be drilled by BP's Coil Tubing Unit, Nordic #1. Drilling commenced in late November and the rig completed the well and moved off in mid-December. The first planned leg was the 02-28A target bottom hole location. This leg was found to be all shale and not economic. Therefore it was plugged back and the 02-28AL 1 target bottom hole location was drilled and completed. Mary Endacott, CT Drilling Engineer, e-mailed Winton Aubert on 12/13/04 describing the situation and how BP proceeded to complete the well, It was not realized until I began the paperwork for the 10-407 for this completed well, that we had a dilemma. The 02-28AL 1 bottom hole location is significantly different from the 02-28A bottom hole location. I would like to propose that we consider Mary Endacott's e-mail to Winton Aubert as a "Change Approved Program". Therefore the first bottom hole location becomes 02-28APB1 and the final bottom hole location becomes 02-28A and; the 02-28AL 1 Permit to Drill would be cancelled. I made this proposal to Winton on 01/07/05, seeking guidance as to how to fill out the Completion Report for this well and he advised that I should submit an explanatory letter with the Completion Report for 02-28A. If this is not the solution you desire, please advise me as to how you would like the paperwork submitted and I will submit as soon as possible. Thank you very much for your assistance in this matter. Sincerely, ~ Terrie Hubble . Unocal Alaska 909 w, 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com . {fioclJJ~ 3 UNOCAL Debra Oudean G & G Technician Date: September 17, 2004 To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 KGSF7&7A URVEYS, FINAL LAS FILES, LITHOLOGICAL UMMARY, MORNING REPORTS, MUD ABLE, OPERATIONAL SUMMARY éI eturning one copy of this transmittal or FAX to (907) 263-7828. Date: · , ~ FRANK H. MURKOWSKI. GOVERNOR AI/ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. ?T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 02-28A BP Exploration (Alaska) Inc. Permit No: 204-164 Surface Location: 273' SNL, 796' EWL, SEC. 36, T11N, R14E, UM Bottomhole Location: 1381' NSL, 1362' WEL, SEC. 26, T11N, R14E, UM Dear Mr. Johnson: 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 'tness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 7 ager). · STATE OF ALASKA . ALASð OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 W6A- i/3011.&iC)lf RECEIVED AUG 272004 Alaska Oil & Gas Cons. CommissiQt't o Drill B Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 273' SNL, 796' EWL, SEC. 36, T11 N, R14E, UM Top of Productive Horizon: 1328' NSL, 1783' WEL, SEC. 26, T11 N, R14E, UM Total Depth: 1381' NSL, 1362' WEL, SEC. 26, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 687530 y- 5950926 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 9835 feet Maximum Hole Angle: 91 dearees 1b. Current Well Class 0 Exploratory B Development Oil 0 rAßÐ.~_ I 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: IBI Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU 02-28A /' 6. Proposed Depth: 12. Field / Pool(s): MD 11750 rvD 894555 Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool ADL 028308 8. Land Use Permit: 13. Approximate Spud Date: September 10, 2004 14. Distance to Nearest Property: 34,320' / 9. Acres in Property: 2560 3" Weiaht 6.2# Specifications Grade CouDlina Lenath L-80 STL 1400' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 62' feet 02-08A is 567' away at 11411' MD 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.0~ Downhole: 3500 Surface: 2620 TI :~ttí!'l~Dept~i. 1"",Xc.f. '" -. MD rvD MD rvD (includinJ staae data) 10350' 8939' 11750' 8945' Uncemented Slotted Liner / 18. casing program: Size Casina 2-3/8" Hole 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth rvD (ft): Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft): 10221 9142 None 10167 9093 .........IIM I . Size . MU 0: . Junk (measured): None TVO I r.nnrh (~tnr 112' 20" ? 150# Poleset 112' 112' 3488' 10-3/4" 1000 sx CS III, 350 sx 'G'; TJ: 152 sx CS II 3488' 3488' 9301' 7-5/8" 50 sx Class 'G' 9301' 8345' P n I inør 1223' 5-1/2" 125 sx Class 'G' 8993' - 10216' 8100'- 9137' Perforation Depth MD (ft): 10035' - 10087' 20. Attachments IBI Filing Fee, $100 IBI BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth rvD (ft): 8975' - 9021' IBI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report IBI Drilling Fluid Program IBI 20 AAC 25.050 Requirements Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Mark Johnson ~ Title CT Drilling Engineer Sianature r )1/LJuL (). \L~ -- Phone 564-5666 Date i,f'''''" " /i~t.iii:iri '¡:¡'ffi" ~~:~~~o~~ t,I- / ~ ¿¡ I API t!¢b~~_ 029-22012-01-00 6:~~it Approval Conditions of Approval: Samples Required 0 Yes ~No Mud Log Required Hydro ulfide Measures ~es 0 No Directional Survey Required ~~ T'(3~~ ;soo fr; p~' C .0 ç¡ & 'O::O~DBY Anmoved B;;-r' --7 ~ ø"~ \. ~ ,¡ THE COMMISSION Form 1 0-401 Re~ 06/200V L.. U Contact Mark Johnson, 564-5666 Prepared By Neme/Number: Terrie Hubble, 564-4628 .- .. I See cover letter for other requirements DYes )!No ~Yes 0 No Date rihcf/ ¥brryf' In OOplicate . . 02-28A & 02-28AL 1 Sidetrack - Coiled Tubing Drilling Summary of Ooerations: Coiled tubing drilling will sidetrack we1l2-28A. These horizontal laterals (2-28A & ALl) will target Zone 1A sand reserves for production. The Zone 1A Sand perforations in the existing well, 2-28 will be isolated with cement / pumped past the whipstock. CTD Drill and Comolete 2-28A & 2-28 ALl or02ram: Planned for Seotember 10. 2004 1. Pre CTD install mechanical whipstock at approx 9930'. 2. Pre CTD pump approx. IObbls 15.8ppg cement past whipstock. Clean out to whipstock face. 3. MIRUNordic 1. NU 7-1/16" BOPE, and test. 4. Mill 2.74" window at 9930' md and 10' of openho1e. 5. Drill 3" bicenter hole horizontal sidetrack 02-28A from window to ~ 11,750' TD targeting Zone 1A sand / interval, 6. Run and drop a 2-3/8" slotted (pre-drilled) liner from TD of 11,750', up to 10,350' md. / 7. Openhole sidetrack at 10,350', off the 2-3/8" liner deployment sleeve. 8. Drill 3" bicenter horizontal sidetrack 02-28AL1 from open-hole side track to ~ 11,850' TD targeting Zone /" 1A sand interval. 9. Complete with combined 23/8" solid/pre-drilled liner from the TD of ALl at 11,850', up into the 3-1/2" M:í;$" -.. g to ~901O'. A cementing sub will be placed at 10,250'. The solid liner will be ce~ted in place with / ~ bI15.8~pg ce~ent target TO~ at 9600. 1 (},-.st CTD ng - Bnng on productIOn. Mud Program: · Steps 1-4: 8.4 brine · Steps 5-10: 8.7 ppg used Flo-Pro or biozan for milling, new Flo Pro for drilling. / Disposal: · Class II drill solids to Grind & Inject at PBU Drillsite 4 · Class I wastes will go to Pad 3 for disposal. Casing Program: · 02-28A: 23/8",6.2#, L-80, STL slotted liner from 11,750' md to 10,350' md · 02-28AL1: 23/8",6.2#, L-80, STL slotted liner from 11,850' md to 10,300' md · 02-28AL1: 23/8",6.2#, L-80, STL solid liner from 10300' md to 9,010' md / Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4500 psi. / · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plans for 02-28A & 02-28A L1 · Magnetic and inclination surveys will be taken every 30 ft. · The nearest well to 02-28A will be 567' ctr - ctr from well 02-08A @ 11,411 md; 1,035' from well 02-08B / at 11,275' md and 1139' from 02-30B @ 10,800'. · The nearest well to 02-28AL1 will be 1092' ctr - ctr from well 02-30B @ 10,875' md; 1,189' from well 02- 30BPB1 @ 10,850' and 655' from well 07-33A @ 11,500' md. Logging · A Gamma Ray log will be run over all of the open hole section. 1/2 . . 02-28A & 02-28AL 1 Sidetrack - Coiled Tubing Drilling Hazards · Drillsite 2 i~an IDS pad. 2·28 has <10 ppm IDS. /' · No fault crossings expected in either lateral. · No Loss circulation expected. · Gas is present in Zone lB. · IA Leak in casing at 5970 - 6050 squeezed with Maraseal Sept 1994 still holding. Production tubing will,ge pressure tested to 3000 psi in advance of sidetrack. · Cement off open junction of laterals. · Targets are west of a major N·S fault. An E-W fault is 400' away from the proposed subsurface location of 02-28ALl Reservoir Pressure · Reservoir pressure is approx. 3500 psi at 8800' TVD 7.7 ppg EMW. Max. surface pressure with gas (0.1 psi/ft) to surface is 2620 psi. / Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling. ªøtî:~~~~RQì 2/2 lREE= - ? WELLHEAD = FMC SAFETY NOTES: ***IAx FORM COMMUNICATION, AClUATOR= AXB.SON 02-28 5970'-6050'. IAGB. SQZ. OPERATING UMITS: MAX KB. ELBI = 62.0' lAP = 500 PSI; MAX OAP = 1000 PSI (08122/03 BF. ELBI = W AlVER)*** DON'T RUN LGLV's, IA LOADED KOP= 4100' W BRINE OVER CRET LEAK II.1ax Angle = 39 @ 6900' . Q¡turn MJ = 9908' I 2186' 4-1/2" AVA lRSV SSSVNP, ID=3.812" I Q¡turn 1V D = 8800' SS 4-1/2" TBG-Fe, 12.6#, L-80, .0152 bpf, ID = 3.958" 2208' t- - - 2208' 4-1/2" X 3-1/2" XO, D =2.867" I 2208' --- - --- TOP OF 3-1/2" TBG-PC ~~ 298~ ~ 2 GAS LIFT MANCRELS emMA TED CMT TOP ST MD TVD œv 1YÆ VLV LA TCH PORT DATE 110-314" CSG, 45.5#, J-55, ID = 9.953" 348~ 1 3189 3189 1 CAMCO RK 2 5206 5104 35 CAMCO RK 17-518" CSG, 29.7#, L-SO, ID =6.875' H 4689' 1 3 6604 6217 37 CAMCO RK , 4 7098 6603 38 CAMCO RK ITOPOF 7-518" CSG H 4689' I U 5 7405 6847 38 CAMCO RK 6 8238 7505 38 CAMCO RK 7 8487 7700 38 CAMCO RKP Minimum ID = 2.75" @ 9017' 8 8827 7969 38 CAMCO RK 3·112" OTIS XN NPPLE :8: ~ I 8918' 7-518" X 3-1/Z' OTIS BWD A<R. 10 = 4.00" ""'-"'" ITOPOF 5-1/2" LNR 8993' I I I . I 901T 3-1/2" OllS XN NP, ID = 2.75" I 3-1/Z' TBG-PC, 9.3#, L-80, .0087 bpf, ID= 2.992" 9028' I 9028' 3-1/2" TUBING TAIL, ID = 2.97" I I I 9027' H ELMD TT LOGGBJ 05/08/90 I I 7 -51B" CSG. 29.7#, L-SO, ID = 6.875" 9300' ~ ~ ÆRFORA TION SUMlilARY REF LOG: BrcS ON 03/12/90 ANGLE AT TOP ÆRF: Z7 @ 10035' No1e: Refer to Production DB for histori::al perf data SIZE SA" INTERVAL Opn/Sqz DATE 3-3/8" 4 10035 - 10044 0 03/29/90 3-3/8" 4 10046 - 10070 0 03/29/90 3- 3/8" 8 10070 - 10087 0 03/29/90 R3TO 10167' I 5-lIZ' Lf'R.17#, L-SO, .0232 bpf, ID =4.892" 10216' I TO 10221' I QUE RBI BY COMvlB'llTS 0/.\1E REV BY COMfvEN1S PRLDHOE BA Y UNT 03/17/90 ORIGINAL COM PLETION WELL: 02-28 OS/25/01 RN'TP CORRB:;TIONS PERMIT No: 1900220 03/10/03 JI\IPIW WANER SAFETY NOTE AR No: 50-029-22012-00 06/11/03 CMOITLP KB ELBI A TION CORREcrlON SEC 3, T11N, R14E, 2122.28' FB. & 3777.19' FNL 08/22/03 JR::/KK WANER SAFETY NOTE 12/03 KCF/TLP ESTCMTTOP BP Exploration (Alaska) . . TREE = . WELLHEAD = ~CTUA TOR = KB. B..EV = BF.B.ËV ;,; KOP= 4100' Max Angle = 39 @ 6900' . _ _ .... Datum MD = 9908' Datum TVD = 8800' 55 14-112" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" TOPOF 3-1/2" TBG-PC I I ESTIMA TED CMT TOP I 110-3/4" CSG, 45.5#, J-55, ID = 9.953" I 17-S/8" CSG, 29.7#, L-80, ID = 6.87S" 1-1 TOPOF 7-5/8" CSG H ? FMC .. _ d n__ _. AXB..50N 62.0' .2-28A & AL 1 Proposed CTO Multilaterals S NOTES: ***IA x FORM COMMUNICATION, 597 -6050'. IA GEL SQZ. OPERATING LIMITS: MAX lAP = 500 PSI; MAX OAP = 1000 PSI (08/22/03 WAIVER)*** DON'T RUN LGlV's, IA LOADED WIBRlNE OVER CRET LEAK. 4689' 4689' Minimum ID = 2.75" @ 9017' 3-1/2" OTIS XN NIPPLE TOPOF 5-1/2" LNR I 8993' 3-1/2" TBG-PC, 9.3#, L-80, .0087 bpf, ID = 2,992" 9028' 7-5/8" CSG, 29.7#, L-80, ID = 6.87S" 9300' '(Jp ,-'f Cemsf't 9600' ÆRFORA TION SUMMARY REF LOG: BHCS ON 03/12/90 ANGLEATTOPÆRF: 27 @ 10035' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10035 - 10044 isolated proposed 3-3/8" 4 10046 - 10070 !so ¡¡ted proposed 3-3/8" 8 10070 - 10087 ¡solated proposed IPBTD I 10221' 10167' S-1/2" LNR, 17#, L-80, .0232 bpf, ID= 4.892" I 10216' ~ DATE 03/17190 OS/2S/01 03/10/03 06/11/03 08/22/03 12/03 REV BY COMMENTS ORIGINAL COM PLETION RNlTP CORRECTIONS JMPlTP WAIVER SAFETY NOTE CMOITLP KB B..EV A TION CORRECTION JRClKK WAIVER SAFETY NOTE KCFITLP EST CMT TOP DATE 6) 2186' -i4-1/2" AVA TR5V SSSV NIP, ID=3.812" 2208' -14-1/2" X 3-112" XO, ID = 2.867" I ST MD TVD 1 3189 3189 2 S206 S104 3 6604 6217 4 7098 6603 5 740S 6847 6 8238 7S05 7 8487 7700 8 8827 7969 GAS LIFT MANDRELS DEV TYÆ VLV LATCH 1 CAMeo RK 35 CAMeo RK 37 CAMCo RK 38 CAMeo RK 38 CAMeo RK 38 CAMeo RK 38 CAMeo RKP 38 CAMeo RK FORT DATE 8918' -17-5/8" X 3-1/2" OTIS BWD A<:R, 10 = 4.00" 0010' 1-i2'318"Uner Toµ I 9017' -l3-1/2" OTIS XN NIP, 10 = 2.75" I 9028' 9027' -i3-1/2" TUBING TAIL, 10 = 2,97" I H B..MO TT LOGGED 05/08190 I I I 10250' I "8onz!3~' cem:mt¡ng sub(bottomof cerrenfi ?~ \ >.. \ \ 2-2M L 1 : 2·3i8" pre·drmed liner 1-; 11850' '-. \; \ , '-., ,,\ ¡ ""'(;4>" \ ¿~;~~~nctiog.r- 0 º 0 0 0 0 Q Q Q 1 '?><'~"c,,,,J \../</. .................. "'·<..[~=;J..r:r~:::::(j:3L o::þ:: 0 3L:Þ 3CQ:: ¡=q \.10300' xo solid to pnHIrilled liner ¡ 2-28A : 2-3!8" pr€\·drmed liner H 11750' 9930' l-i Me<;hanicaIV</hipstr.¡';k REV BY PRUDHOE BAY UNrr WELL: 02-28 ÆRMrr No: 1900220 API No: 50-029-22012-00 SEC 3, T11 N, R14E. 2122.28' FEL & 3777.19' FNL COMMENTS BP Exploration (Alaska) Plan: P1an #13 (02~28¡Plan#13 02-28A) Created By: Bnj Potr\is Date: 8/10/2004 Azimuth$ to True North Magnetic North: 25.20' Magnetic Fieid Strength: 57620nT D~a¿~g¿M~85; Model: bggm2004 M P T1N'ø-t BP Amoco WELl-PAnt DETAILS Pllut#1:t024:8A $OO2e2t012Ô1 Panmt W.upatiu ..... Tkfofl MD: HOT.$O RIo' Nordic 2: Rd".Ðabum .. : 28 2:/27/199& 00:$0 62.00ft V.s.cuø" ".'IIe!: ~æ= ~=itm ..... 93.00' 0..00 .... 32.00 REFERENCE INFORMA nON .. ... ... "I. ..."" ..e:1-W' ÞLtI J TAtee . . Obp BP-GDB Baker Hughes INTEQ Planning Report ..-: INT&Q Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB DS 02 TR-11-14 UNITEI:¡> STATES: North Slope Site Position: Northing: From: Map, Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948800.37 ft 687638,44 ft Latitude: 70 15 Longitude: 148 28 North Reference: Grid Convergence: 53.847 N 58.060 W True 1.43 deg WeD: 02-28 Slot Name: 28 02-28 Well Position: +N/-S 2127.98 ft Northing: 5950926.17 ft Latitude: 70 16 14.776 N +E/-W -55.69 ft Easting : 687529.73 ft Longitude: 148 28 59,681 W Position Uncertainty: 0.00 ft WeDpath: Plan#1302-28A 500292201201 Current Datum: 56: 28 2/27/1990 00:00 Magnetic Data: 8/10/2004 Field Strength: 57620 nT Vertical Section: Depth From (fVO) ft 32.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 02-28 9807.50 ft Mean Sea Level 25.20 deg 80.85 deg Direction deg 93.00 Height 62.00 ft Targets 02-28A Polygon13,1 0.00 1827.47 -2808.24 5952683.00 684677.00 70 16 32.744 N 148 3021.454 W -Polygon 1 0.00 1827.47 -2808.24 5952683.00 684677.00 70 16 32.744 N 148 3021.454 W -Polygon 2 0.00 1870.77 -3060.26 5952720.00 684424.00 70 16 33.169 N 148 3028.792 W -Polygon 3 0,00 2143.70 -3013.44 5952994.00 684464.00 70 16 35,853 N 148 30 27,432 W -Polygon 4 0.00 2348.53 -2883.29 5953202.00 684589.00 70 16 37.868 N 148 30 23,645 W -Polygon 5 0.00 2467.39 -2675.25 5953326,00 684794,00 70 16 39.038 N 148 30 17.588 W -Polygon 6 0.00 2484.01 -2458.76 5953348.00 685010.00 70 16 39.202 N 148 30 11.283 W -Polygon 7 0.00 2385.44 -2277.15 5953254.00 685194,00 70 16 38.234 N 148 30 5.994 W -Polygon 8 0.00 2170.81 -2094.43 5953044.00 685382.00 70 16 36.123 N 148 30 0.671 W -Polygon 9 0.00 1878.89 -2061.69 5952753.00 685422.00 70 16 33.252 N 148 29 59.715 W -Polygon 10 0.00 1581.22 -1999.08 5952457,00 685492.00 70 16 30.325 N 148 29 57.890 W -Polygon 11 0.00 1499.97 -2231.19 5952370.00 685262.00 70 16 29.525 N 148 30 4.648 W -Polygon 12 0.00 1694,17 -2316.38 5952562.00 685172,00 70 16 31.435 N 148 30 7.130 W -Polygon 13 0.00 1880.34 -2320.75 5952748.00 685163.00 70 16 33.266 N 148 30 7.259 W -Polygon 14 0.00 2050.25 -2314.51 5952918.00 685165.00 70 16 34.937 N 148 30 7.079 W -Polygon 15 0.00 2165.61 -2447.69 5953030,00 685029.00 70 16 36.071 N 148 30 10.958 W -Polygon 16 0.00 2200.52 -2603.87 5953061.00 684872.00 70 16 36.414 N 148 30 15.506 W -Polygon 17 0.00 2146.82 -2737.26 5953004.00 684740.00 70 16 35.885 N 148 30 19.390 W -Polygon 18 0,00 2005.83 -2779.79 5952862.00 684701.00 70 16 34.498 N 148 3020.627 W -Polygon 19 0.00 1824.40 -2805.32 5952680.00 684680.00 70 16 32.714 N 148 3021.368 W 02-28A Fault 1 0.00 2789.60 -4524.91 5953602.00 682937.00 70 1642.198 N 148 31 11.457 W -Polygon 1 0.00 2789.60 -4524.91 5953602.00 682937,00 70 1642.198 N 1483111.457W -Polygon 2 0.00 2802.17 -2781.95 5953658,00 684679.00 70 16 42.330 N 148 30 20.698 W 02-28A Fault 3 0.00 3059.41 -2747.53 5953916.00 684707.00 70 16 44.860 N 148 30 19.699 W -Polygon 1 0.00 3059.41 -2747.53 5953916.00 684707.00 70 16 44.860 N 148 30 19.699 W -Polygon 2 0.00 2849.24 -2101.53 5953722.00 685358,00 70 16 42.795 N 148 30 0.883 W 02-28A Fault 2 0.00 2663.34 -2790.41 5953519.00 684674.00 70 16 40.965 N 148 30 20.943 W -Polygon 1 0.00 2663.34 -2790.41 5953519.00 684674.00 70 16 40.965 N 148 30 20.943 W -Polygon 2 0.00 3059.41 -2747,53 5953916.00 684707.00 70 16 44.860 N 148 30 19.699 W . . Obp BP...GDB Baker Hughes INTEQ Planning Report ... ..... INTEQ 02-28A Fault 4 0.00 2849.24 -2101.53 5953722.00 685358.00 70 16 42.795 N 148 30 0.883 W -Polygon 1 0.00 2849.24 -2101.53 5953722.00 685358.00 70 16 42.795 N 148 30 0.883 W -Polygon 2 0.00 1912.39 -1920.80 5952790.00 685562.00 70 16 33.582 N 148 29 55.613 W -Polygon 3 0.00 1140.54 -1255.79 5952035.00 686246.00 70 1625.992 N 148 2936.245 W -Polygon 4 0.00 1912.39 -1920.80 5952790.00 685562.00 70 16 33.582 N 148 29 55.613 W 02-28A Fault 6 0.00 1857.40 -3286.68 5952701,00 684198.00 70 16 33.037 N 148 3035.385 W -Polygon 1 0.00 1857.40 -3286.68 5952701.00 684198.00 70 16 33.037 N 148 30 35.385 W -Polygon 2 0.00 1510.81 -3308.32 5952354.00 684185.00 70 16 29.628 N 148 3036.011 W -Polygon 3 0.00 1292.78 -3470.81 5952132.00 684028.00 70 16 27.483 N 148 30 40.739 W -Polygon 4 0.00 1510.81 -3308.32 5952354.00 684185.00 70 16 29,628 N 148 30 36.011 W 02-28A Fault 7 0.00 1660.14 -3720.75 5952493,00 683769.00 70 16 31,095 N 148 30 48.022 W -Polygon 1 0.00 1660.14 -3720.75 5952493.00 683769.00 70 16 31.095 N 148 30 48.022 W -Polygon 2 0.00 758.86 -3161.00 5951606,00 684351.00 70 16 22.233 N 148 3031.712 W 02-28A Fault 5 0.00 1485.76 -2463.63 5952350.00 685030.00 70 16 29.385 N 148 30 11.416 W -Polygon 1 0.00 1485.76 -2463.63 5952350.00 685030.00 70 16 29.385 N 1483011.416W -Polygon 2 0.00 1265.95 -1992.93 5952142.00 685506.00 70 16 27.224 N 148 29 57,708 W 02-28A T13.1 8941,00 1972.60 -2931.67 5952825.00 684550.00 70 16 34.171 N 148 30 25.049 W 02-28A T13.2 8943.00 2221.14 -2267.24 5953090,00 685208.00 70 16 36.618 N 148 30 5.704 W 02-28A T13.3 8945.00 1628.49 -2169.97 5952500.00 685320.00 70 16 30.789 N 148 30 2.866 W Annotation 9807.50 8711,88 TIP 9835.00 8735.83 KOP 9855.00 8753.12 end 9 DLS I begin 19 DLS 9905,00 8793.78 4 10253.96 8941.14 5 10353.96 8938.85 6 10503.96 8937.71 end 19 DLS I begin 15 DLS 10903.96 8941.99 8 11303.96 8944.13 9 11503.96 8944.74 10 11750.00 8945.39 TO Plan: Plan #13 Date Composed: 8/10/2004 Identical to Lamar's Plan #13 Version: 2 Principal: Yes Tied-to: From: Definitive Path Plan Section Informaôon 9807.50 29.55 296.89 8711,88 1688.03 -2753.03 0.00 0.00 0,00 0.00 9835.00 29.30 297.07 8735.83 1694.16 -2765.07 0.96 -0.91 0.65 160.60 9855.00 31.00 298,27 8753.12 1698.82 -2773.97 9.00 8.49 5.98 20.00 9905.00 40.04 303.30 8793.78 1713.78 -2798.81 19.00 18.09 10.07 20.00 10253,96 91.00 353,09 8941.14 1978.86 -2928.42 19.00 14.60 14.27 56.50 10353.96 91.60 12.08 8938,85 2078.27 -2923.93 19.00 0.60 19.00 88.00 10503.96 89.26 40.49 8937.71 2211.37 -2858.17 19.00 -1.56 18.94 94.50 10903,96 89.63 100.49 8941,99 2338.91 -2498.15 15.00 0.09 15.00 90.00 11303,96 89.81 160.49 8944.13 2090.87 -2207.67 15,00 0.05 15.00 90.00 11503.96 89,84 190.49 8944.74 1893.76 -2192.14 15.00 0.01 15.00 90,00 11750.00 89.87 153.59 8945.39 1654.28 -2158.66 15,00 0.01 -15.00 270,00 . . Obp BP-GDB Baker Hughes INTEQ Planning Report -..I: INTRQ 9807.50 29.55 296.89 8711.88 1688.03 -2753.03 5952544.98 684735.66 -2837.60 0.00 0.00 TIP 9825.00 29.39 297.00 8727.11 1691.93 -2760.71 5952548.69 684727.89 -2845.47 0.96 160.60 MWD 9835.00 29.30 297.07 8735.83 1694.16 -2765.07 5952550.81 684723.48 -2849.95 0,96 160.50 KOP 9850.00 30.57 297,98 8748.83 1697.62 -2771.71 5952554.10 684716.75 -2856.76 9.00 20.00 MWD 9855.00 31.00 298.27 8753.12 1698.82 -2773.97 5952555.25 684714.47 -2859.08 9.00 19.21 end 9 DL 9875.00 34.59 300.55 8769.93 1704.15 -2783.40 5952560;34 684704.91 -2868.77 19.00 20.00 MWD 9900.00 39.13 302.89 8789.93 1712.04 -2796.14 5952567.91 684691.98 -2881.91 19.00 18.08 MWD 9905.00 40.04 303.30 8793.78 1713.78 -2798.81 5952569.59 684689.26 -2884.66 19.00 16.21 4 9925.00 42.24 308.01 8808.85 1721.46 -2809.48 5952576..99 684678.40 -2895,73 19.00 56.50 MWD 9950,00 45.23 313.36 8826,92 1732.73 -2822.56 5952587,94 684665.04 -2909.38 19.00 52.95 MWD 9975.00 48,44 318.15 8844.02 1745.80 -2835.26 5952600,68 684652.02 -2922.75 19.00 49.09 MWD 10000.00 51.84 322.48 8860.05 1760.57 -2847.50 5952615.15 684639.43 -2935.74 19,00 45.80 MWD 10025.00 55.38 326.42 8874.88 1776.95 -2859.18 5952631.22 684627.34 -2948,26 19.00 43.02 MWD 10050.00 59.03 330.03 8888.42 1794.81 -2870.23 5952648.81 684615.85 -2960.23 19.00 40.69 MWD 10075.00 62.78 333.37 8900.58 1814.05 -2880.57 5952667.78 684605.03 -2971.56 19.00 38.73 MWD 10100.00 66.61 336.49 8911.26 1834.51 -2890.14 5952688.00 684594.96 -2982.19 19.00 37.11 MWD 10125.00 70.49 339.43 8920.41 1856.08 -2898.86 5952709.34 684585.71 -2992.02 19.00 35.77 MWD 10150.00 74.41 342.24 8927.95 1878.59 -2906.67 5952731.64 684577.33 -3001,01 19.00 34.69 MWD 10175.00 78.37 344.94 8933.83 1901.89 -2913.53 5952754.77 684569.89 -3009.08 19.00 33.85 MWD 10200.00 82.36 347.56 8938.01 1925.83 -2919.39 5952778.$5 684563.45 -3016.18 19.00 33.21 MWD 10225.00 86.36 350.13 8940.47 1950.23 -2924.20 5952802.82 684558.03 -3022.26 19,00 32.77 MWD 10250.00 90.37 352.69 8941.18 1974.93 -2927.93 5952827.42 684553.69 -3027.27 19.00 32.52 MWD 10253.96 91.00 353.09 8941.14 1978.86 -2928.42 5952831,33 684553.10 -3027.97 19.00 32.45 5 10275.00 91.14 357.09 8940.74 1999.81 -2930.22 5952852.24 684550.78 -3030.86 19.00 88.00 MWD 10300.00 91.29 1.83 8940.21 2024.80 -2930.45 5952877.21 684549.92 -3032.41 19.00 88,07 MWD 10325,00 91.44 6.58 8939.62 2049.72 -2928.62 5952902.16 684551.13 -3031.88 19.00 88.18 MWD 10350.00 91,58 11,33 8938.96 2074.40 -2924.73 5952926.93 684554.40 -3029.29 19.00 88.29 MWD 10353.96 91.60 12.08 8938.85 2078.27 -2923.93 5952930.82 684555.11 -3028.69 19.00 88.41 6 10375.00 91.28 16.07 8938.32 2098.67 -2918.81 5952951.34 684559.72 -3024.65 19,00 94.50 MWD 10400.00 90.89 20.81 8937.85 2122.38 -2910.91 5952975.24 684567.03 -3017,99 19.00 94.60 MWD 10425.00 90.50 25.54 8937.54 2145.35 -2901.07 5952998.45 684576.28 -3009.38 19,00 94.69 MWD 10450.00 90.11 30.27 8937.41 2167.44 -2889.37 5953020.82 684587.43 -2998.85 19.00 94.75 MWD 10475,00 89.71 35.01 8937.45 2188.48 -2875.89 5953042.19 684600.38 -2986.49 19.00 94.77 MWD 10500.00 89.32 39.74 8937.66 2208.34 -2860.72 5953062.42 684615,05 -2972.38 19.00 94,77 MWD 10503.96 89.26 40.49 8937.71 2211.37 -2858.17 5953065.51 684617.52 -2969.99 19.00 94.73 end 19 D 10525.00 89.26 43.65 8937.98 2226.99 -2844.08 5953081.47 684631.23 -2956.73 15.00 90.00 MWD 10550.00 89.26 47.40 8938.30 2244.50 -2826.24 5953099.42 684648.62 -2939.84 15,00 89.96 MWD 10575.00 89.27 51.15 8938.62 2260.80 -2807.30 5953116.19 684667,14 -2921.78 15.00 89.91 MWD 10600.00 89.28 54.90 8938.94 2275.84 -2787.33 5953131.72 684686.73 -2902.62 15.00 89.86 MWD 10625.00 89.30 58.65 8939.25 2289.53 -2766.43 5953145.93 684707.29 -2882.46 15.00 89.82 MWD 10650.00 89.31 62.40 8939.55 2301.83 -2744.67 5953158.77 684728.73 -2861.38 15.00 89.77 MWD 10675.00 89.33 66.15 8939.85 2312.68 -2722.15 5953170.17 684750.97 -2839.46 15.00 89.72 MWD 10700.00 89.35 69.90 8940.13 2322.03 -2698.97 5953180.10 684773,91 -2816.80 15.00 89.68 MWD 10725.00 89.38 73.65 8940.41 2329.85 -2675.23 5953188.50 684797.44 -2793.50 15.00 89.64 MWD 10750.00 89.41 77.40 8940.67 2336.10 -2651.03 5953195.35 684821.48 -2769.66 15,00 89.59 MWD 10775.00 89.44 81.15 8940.93 2340.75 -2626.48 5953200,61 684845.91 -2745.38 15.00 89.55 MWD 10800.00 89.47 84.90 8941.16 2343,78 -2601.67 5953204.26 684870.64 -2720.76 15.00 89.52 MWD 10825.00 89.51 88.65 8941.39 2345.19 -2576.71 5953206.29 684895.55 -2695,92 15.00 89.48 MWD 10850,00 89.54 92.40 8941.60 2344.96 -2551.72 5953206.69 684920.54 -2670.95 15.00 89.45 MWD 10875.00 89.58 96,15 8941.79 2343.10 -2526.79 5953205.44 684945.50 -2645.96 15.00 89.42 MWD 10900.00 89.62 99.90 8941.96 2339,61 -2502.04 5953202.57 684970.33 -2621.06 15.00 89.39 MWD 10903.96 89.63 100.49 8941.99 2338.91 -2498.15 5953201.97 684974.24 -2617.13 15.00 89,36 8 10925.00 89.63 103.65 8942.12 2334,51 -2477,57 5953198.08 684994.91 -2596.36 15.00 90.00 MWD . . ObP BP-GDB Baker Hughes INTEQ Planning Report ... .... INTB.Q 10950.00 89.63 107.40 8942.28 2327.82 -2453.49 5953192.00 685019.16 -2571.96 15.00 89.98 MWD 10975.00 89.64 111.15 8942.44 2319,56 -2429.90 5953184.34 685042.95 -2547.96 15.00 89.96 MWD 11000.00 89,64 114.90 8942.60 2309.79 -2406.89 5953175.14 685066.18 -2524.48 15.00 89.93 MWD 11025.00 89.65 118.65 8942.76 2298.53 -2384.58 5953164.44 685088.77 -2501.60 15.00 89.91 MWD 11050.00 89.66 122.40 8942.91 2285.83 -2363.05 5953152.28 685110.61 -2479.44 15.00 89.88 MWD 11075,00 89.67 126.15 8943,06 2271.76 -2342.39 5953138.72 685131.61 -2458.08 15.00 89.86 MWD 11100.00 89.68 129.90 8943.20 2256.36 -2322.70 5953123.82 685151.67 -2437.61 15.00 89.84 MWD 11125.00 89.69 133.65 8943.34 2239.71 -2304.06 5953107.64 685170.72 -2418.12 15.00 89.82 MWD 11150.00 89.70 137.40 8943.47 2221.87 -2286.55 5953090.25 685188.67 -2399.70 15.00 89.80 MWD 11175.00 89.72 141.15 8943.60 2202.93 -2270.24 5953071.72 685205.45 -2382.42 15.00 89.78 MWD 11200.00 89.74 144.90 8943.71 2182.96 -2255.21 5953052,13 685220.97 -2366.37 15.00 89.76 MWD 11225.00 89.75 148.65 8943.83 2162.05 -2241.51 5953031.57 685235.18 -2351.60 15.00 89.74 MWD 11250.00 89.77 152.40 8943.93 2140.29 -2229.22 5953010.13 685248.02 -2338.17 15.00 89.72 MWD 11275.00 89.79 156.15 8944.03 2117.77 -2218.37 5952987.89 685259.42 -2326.16 15,00 89.71 MWD 11300.00 89.81 159.90 8944.11 2094.59 -2209.01 5952964.95 685269.35 -2315.61 15.00 89.69 MWD 11303.96 89.81 160.49 8944.13 2090.87 -2207.67 5952961.26 685270.78 -2314.08 15.00 89.68 9 11325.00 89.81 163,65 8944.19 2070.85 -2201.20 5952941.41 685277,76 -2306.56 15.00 90.00 MWD 11350.00 89.82 167.40 8944.27 2046.65 -2194.95 5952917.37 685284.61 -2299,05 15.00 89.99 MWD 11375.00 89.82 171.15 8944.35 2022.09 -2190.30 5952892.94 685289.87 -2293.12 15.00 89.98 MWD 11400.00 89.82 174.90 8944.43 1997.28 -2187.26 5952868.21 685293.52 -2288.79 15.00 89.97 MWD 11425.00 89.82 178.65 8944.51 1972.32 -2185.86 5952843.30 685295.55 -2286.08 15.00 89.95 MWD 11450.00 89.83 182.40 8944.59 1947.33 -2186.09 5952818.31 685295.94 -2285.01 15.00 89.94 MWD 11475.00 89.83 186.15 8944.66 1922.40 -2187.95 5952793.35 685294.70 -2285.56 15.00 89.93 MWD 11500.00 89.84 189.90 8944.73 1897.65 -2191.44 5952768.52 685291.83 -2287.75 15.00 89.92 MWD 11503.96 89.84 190.49 8944.74 1893.76 -2192.14 5952764.61 685291.22 -2288,25 15.00 89.91 10 11525.00 89.84 187.34 8944.80 1872.97 -2195.40 5952743.75 685288.48 -2290.42 15.00 270.00 MWD 11550,00 89.84 183.59 8944,87 1848.09 -2197.78 5952718.82 685286.72 -2291.49 15.00 270.01 MWD 11575.00 89.84 179.84 8944.94 1823.10 -2198.53 5952693.82 685286.60 -2290.93 15.00 270.02 MWD 11600.00 89.84 176.09 8945.01 1798.13 -2197.64 5952668.88 685288.11 -2288.73 15.00 270.03 MWD 11625.00 89.85 172,34 8945.08 1773.26 -2195.12 5952644.08 685291.25 -2284.92 15.00 270.04 MWD 11650.00 89.85 168,59 8945.14 1748.61 -2190.98 5952619.54 685296.00 -2279.49 15.00 270.05 MWD 11675.00 89.86 164.84 8945.21 1724.28 -2185.23 5952595.37 685302.35 -2272.48 15.00 270.06 MWD 11700.00 89.86 161.09 8945.27 1700.38 -2177.91 5952571.66 685310.27 -2263.92 15.00 270.07 MWD 11725.00 /89.87 157.34 8945.33 1677.01 -2169.04 5952548.52 685319.72 -2253.83 15.00 270.08 MWD 11750.00 89.87 153.59 8945.39 1654.28 -2158.66 5952526.05 685330.66 -2242.28 15.00 270.09 TO TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 "Mastercard Check" DATE O?y~7 {)4 I $ /00. CO ß~£ET~o'rE ~~~ IAofð!- O('(L r:xx r:Jð First National Bank Alaska Anchorage, AK 99501 ~ .. ~ ~ MEMO o~·)...ePr Wtu ':.252000(;0':1111.1.11'(; 2 27"· ¡. 55(;11· 0 ¡. 311 139 DOLt.ì~:nC . . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME~ð« 02-~2-gA PTD# :Zo7'-/b~ X' Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS "CLUE", APPLIES (OPTIONS) MULTI The permit is for a new weJlbore segment of LA TERAL existing well . Permit No, API No. . (If API number Production. should continue to be reponed as last two. (2) digits a function 'of the original API number. stated are between 6.0-69) above. PILOT HOLE ]n accordance with 2.0 AAC 25.DD5(f), all (PH) records, data and logs acquired for the pilot hole must be dearly differentiated În both name (name on permit plus PH) " and API number (5.0 - 7.0/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION compliance with 20 AAC 25.055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spa cing exception. (Company Name) assumes the liability of any protest to the spacing .e:Jception tbat may occur. DRY DITCH AU dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater 1ban 30' sample intervals from below tbe permafrost or from where sa.mples are first caught and ] 0' sample intervals through target zones. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 02-28A PTD#:2041640 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV 11-01L GeoArea 890 Unit 11650 1 pß(llJiUee attaçhe.d. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yß$ . . . . . . . . . 2 .Leasßnµmberappropriate. . . . . .. Yes . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . .. ................... 3 .U.n[qµe weltn.arnß.a!ld OUllJb.er . . . . . . . . . _ . . . . . . . . . . . . . . _ . . . . . . . . . . . . . .Yß$ . . . . . . . . . . . . . . . . . . . _ _ . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . 4 We.lUQcatßd in.a. define.d .pool. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yß$ . . . . . . . . . . . . . . . . . . . . .' .................... . . . . . . 5 WelUQcatßd properd[stance. from driJling unitboundal")'. . . . . . . . .Yß$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6 WelUQcatßd proper .d [sta!l ce. from Qther wel!s. . . . . . . . . Yes .. .................... . . . . .. ........ 7S.utfiçientaçreage.ayailable in.drilJiog unjt . . . . . . . . . . . . . . . . . . . . . Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . 8 Jfdßviated, .Is weJlbQre platincJu.ded . . . . . . . . . .Yßs . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . _ . 9 Qper.ator onlY' affeçted party. . . . . . . . . . . . . Yes . . . . . . . . . . . . . 10 .O. )e(ator has.appropr[ate.Qond [nJQrce . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yß$ . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . _ _ . . . . . . . . . . . . . . _ . . . . . . . . . . . . . 11 PßlJ1]it. c.a!l be [s$ued withQut co.n$ervation order. . . . . . . . . . . . . . .Yß$ . . . . . . . . 12 pß (1lJ it ca!l be [s$ued withQut ad.llJinist(ati\(eapprovaJ. . . . . . . . . . . . . . . . . . . . .Yß$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8/30/2004 13 Can permit be approved before 15-day wait Yes 14 WelUQcated w[thin area andsïrata .author[zed by lojectioo Order # (pµt.l0# in.cOOlrneots).(For NA . . . . . . . . . . . . . . . . . . . . . 15 AJlwel!s.wit!1i.n.1l4.rrJite.are.a.of reyiew jdßot[fied (Fo(servjc.e.w.ell only). . _ _ . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . ~ . . . . . . . . . _ _ . . . . . . . . . . . . 16 Pre-produçed i!ljector; .duratiQnof pre-. )ro.ductioo le$s. than 3 months. (For.ser:vi.ce well QnJy) .NA .. ...... .................... . . . . . . . . . . . . . . . . . . . . . . . . . . . 17 .ACMP. finding of CQn.si$te!lCY. h.a$ been .issued. forthi$ projeçt . . . . . . NA . . . . . . . . . . . . Administration Appr RPC Date Engineering Appr Date WGA 8/30/2004 Geology Appr RPC Date 8/30/2004 Program DEV On/Off Shore On Well bore seg Annular Disposal - - - - - - - - - - - - - - - - - - - - - - - - - - ~ D . . Geologic Commissioner: DGs - - - - -- - - - - - - 18 .CO!ldu.ctor st(ingprQvided . . . . . . . . . . . . . . . . . . . .NA 19 .S.ulface.casingprQtec.tsallknownUSDWs.. .. . . . . . . .. . . . .... . . . . . . . NA.... . . . 20CMT v.ol. adeQu.ateto çircul.ate.oncond.uçtor 8. su.rf.C$g . . . . _ . . . . . . . . . . .NA 21 .CMT vol. adeQuate.to tie-i.nJQng .stri!lg tosulf csg . . . . . . . . . . . . . . . . . . . . NA . 22 .CMTwiI!GOYer_aUkoo.w.npro.ductiYehQri~Qn.s. .............. No....... .Slotte.d, .............. ............. 23 .Casiog desig!lS adeÇ1uate for C,T, B_&.perllJafr_o$t. . . . . . . . . . . . . . . . . . . . Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24 .Adequate.tankage.oJ re.serye pit. . . . . . . . . . . . . . . . . . . . . _ . . . . . .Yß$ . CTDU. . . . . . . . . . . . . . . . 25 Jfa.re-d(ilt has.a tOA03 fQr abandQnment beßO apprQved .. ....... .Yß$. . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 Adequate.wellbore.separatjo.n.proposed........ _ . . . . . . . . . _ . . . _ _ . . . . . . . . . Ye$. . . _ . . . . . . . . . . . . . . . . _ . . . . . . _ . . _ . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . _ . . . _ . . . . . . . . 27 Jfdivecter required, dQes it .meet reguJatioos . . . . . . . . . . . . . . . . . . . . NA . . . Sidet(açk. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28 .DriUiog fluid.prQgrallJ $c.hematic.& eC .uipJi$t.adequate. . . . . . . . . . . . . . . . . . . . . . . . . .Yß$ . Max MW8J ppg, . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .' ...... 29 .B.oP.Es,do .they .meet reguJation . Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30 ..BOPE.pre.s$ratiogappropriate;testlo(putp$igin.cOmOlentS). ........ ..... Yes . Tes1t.o.4500psi..MSP2620p$Î. ....... 31 .Choke.rrJanifold çQrrJPlies w/API R,P-53 (May 84). . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yß$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 WQrk wiU occur withoyt.operationshutdQwn. . . . . . . . . . . . . . . . . . . . . . Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ................ 33 .Is prese!lce. Qf H2S gas. prOQable . . . . . . . . . . . . . . . . . . . . . . No. IIIQt.a!l H2S pad. . . . . . . . . . . . . . . . . . . . . . . . . . 34 Meçhanical.cood.it[o!l ofwell$ w[thin AOR verified (For.s.ervice wel) onJy). . NA . . . . . . . . _ . . . . . . . . . . . . . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - -- - - - - - - - 35 Permit ca!l be [s$ued w/o. hydrogen. s.ul.fide Oleas.u(es . . . . . . . . . . . . . . . . . . . . No 36 .D.atapreseoted on. potential overpressure .zone$ . . . . . . . . . . . . . . . . . . . . . . . . . . . NA . . _ . . . 37Sei.sOlic.analys.is. Qf shallow gaszooes. . . . . .. ..... .NA . . . . . . 38 .Seabed .cond]tioo $urvey(if off-shore) . . . . . . . . . . . . . . . . . . . . . . NA . . . . . . 39 . CQntactnarn.elp!1onefor.weekly progressreport$ [exploratol")'o!lIYl . . . . . . . NA . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - -- - - - - - - Date: 8')XJ!j- Engineering Commissioner: Date Public Commissioner Date . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . ;! f) vi ~ f~ ~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Aug 04 10:11:26 2005 }f I], ~g1 Reel Header Service name............ .LISTPE Date.................... .05/0S/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments.. ....... ........STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date.................... .05/0S/04 Origin. . . . . . . . . . . . . . . . . . .STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name.. . ... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2-2SA 500292201201 BP Exploration (Alaska) Inc. Sperry Sun 04-AUG-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 MW0003410649 S. LATZ J. EGBEJIMBA MWDRUN 6 MW0003410649 B. JAHN B. HOLT / B. MWDRUN 7 MW0003410649 B. JAHN B. HOLT / B. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN S MW0003410649 B. JAHN B. HOLT / B. MWDRUN 9 MW0003410649 B. JAHN B. LAULE / R # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 36 llN 14E 273 796 MSL 0) 62.00 30.10 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.000 3.500 902S.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE . . NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THE UPPER PORTION OF THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE 2-28 WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 9832'MD/8733'TVDSS. THE LOWER PORTION IS AN OPEN HOLE SIDETRACK, WHICH EXITS THE 2-28A PB1 WELLBORE AT 9985'MD/8848'TVDSS. 4. MWD RUNS 3, 6 - 9 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. NO DRILLING DATA WERE ACQUIRED ON MWD RUNS 1 AND 2. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY RUN IN THE 2-28A WELLBORE ON 11 DECEMBER 2004. THESE LOG DATA WERE PROVIDED BY D. DORTCH (SIS/BP) ON 29 JULY 2005. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 3, 6 - 9 REPRESENT WELL 2-28A WITH API#: 50-029-22012-01. THIS WELL REACHED A TOTAL DEPTH(TD)OF 11728'MD/8920'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...... .05/08/04 Maximum Physical Record..65535 File Type................LO Previous File Name.... ...STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9753.0 9857.5 STOP DEPTH 11702.5 11725.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9753.0 9761.5 9764.0 9766.0 9768.0 9769.5 9777.0 9779.0 9782.0 9790.5 9838.0 9839.5 9842.5 GR 9749.0 9757.5 9760.0 9762.5 9766.0 9768.5 9775.0 9778.0 9780.5 9790.0 9836.5 9838.0 9841.5 . . 9844.5 9850.0 9855.0 9866.5 9877.0 9880.0 9886.0 9895.5 9902.5 9908.5 9924.5 9935.0 9944.5 9949.5 9955.5 9958.0 9961.0 9965.5 9970.5 9974.5 9980.5 9984.0 9986.5 9993.5 9997.5 10004.5 10015.0 10017.5 10024.0 10027.5 10033.0 10045.0 10052.5 10056.0 10060.5 10065.0 10070.5 10084.5 10090.0 10096.5 10105.5 10113.5 10129.5 10141. 0 10190.0 10204.5 10219.5 10230.5 10287.0 10291. 5 10293.5 10300.5 10313.5 10317.5 10320.5 10329.0 10332.5 10349.5 10353.5 10359.5 10363.0 10366.0 10389.0 10402.5 10405.0 10410.0 10430.0 10462.0 10482.5 10492.0 10499.0 10511.0 10515.0 10536.0 10637.5 10658.5 9843.0 9850.5 9854.0 9865.0 9875.0 9878.0 9886.0 9895.5 9900.0 9905.0 9922.0 9932.5 9941.5 9946.0 9953.0 9955.5 9958.0 9963.0 9968.0 9972.0 9978.5 9981.5 9983.5 9992.5 9997.0 10000.5 10013.5 10016.0 10022.5 10026.5 10034.5 10044.0 10051.0 10054.5 10059.0 10062.5 10069.0 10082.5 10087.0 10094.5 10104.0 10112.5 10126.5 10139.5 10188.0 10203.5 10219.5 10229.5 10287.0 10291.5 10293.5 10299.5 10312.0 10318.5 10320.0 10327.0 10330.0 10347.0 10351.0 10357.0 10361.0 10364.5 10387.5 10400.0 10402.0 10408.5 10427.0 10457.5 10479.0 10488.5 10495.5 10506.5 10512.0 10533.0 10637.0 10660.0 10681. 0 10713.0 10722.0 10729.5 10735.5 10879.0 10882.5 10944.0 10961.0 10966.5 10972.5 10977.5 10986.5 11009.0 11020.5 11032.5 11050.5 11061.0 11070.0 11074.0 11077 . 0 11111 . 0 11126.0 11128.0 11233.0 11235.0 11313.0 11411.0 11429.0 11448.5 11522.5 11535.5 11541.5 11566.5 11570.5 11573.0 11580.0 11583.0 11587.0 11590.5 11596 . 0 11601.0 11613 . 0 11616.5 11633.5 11641.5 11649.0 11654.0 11656.5 11659.0 11662.0 11667.5 11669.5 11673.5 11676.0 11725.5 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: . 10680.5 10713.5 10723.0 10729.0 10735.0 10880.5 10883.5 10947.5 10963.0 10967.5 10975.0 10978.0 10987.5 11007.0 11018.5 11031. 0 11049.0 11060.0 11068.5 11072.0 11075.0 11109.0 11123.5 11126.5 11231. 5 11233.0 11312.5 11409.5 11427.5 11445.5 11520.5 11533.5 11539.5 11564.5 11568.0 11571.0 11578.0 11582.0 11585.0 11588.0 11596.0 11601.5 11613.5 11619.0 11635.5 11643.0 11650.5 11655.5 11658.0 11660.0 11663.0 11668.5 11670.0 11675.0 11677.5 11727.0 BIT RUN NO 3 6 7 8 9 MERGED MAIN PASS. $ . MERGE TOP 9749.0 9985.5 10020.0 10271.0 11591.0 MERGE BASE 9985.0 10020.0 10271. 0 11591.0 11727.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type. ....0 Logging Direction............. ....Down Optical log depth units....... ....Feet Data Reference Point............. . Undefined . . Frame Spacing........... ...... ....60 .1IN Max frames per record. . . .. . . . .... . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD MWD Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9753 11725.5 10739.3 3946 9753 11725.5 ROP MWD FT/H 0.01 1494.46 63.466 3737 9857.5 11725.5 GR MWD API 15.08 766.66 78.9911 3821 9753 11702.5 First Reading For Entire File..... .....9753 Last Reading For Entire File. .... ......11725.5 File Trailer Service name........ .... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/08/04 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..... ..05/08/04 Maximum Physical Record. .65535 File Type.... . . . . . . . . . . . . LO Previous File Name... ... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 3 .5000 START DEPTH 9749.0 9856.5 STOP DEPTH 9985.0 9985.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 01-DEC-04 Insite 8.01 Memory 9985.0 9856.0 9985.0 44.2 91.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER . 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 Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units...........Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD030 GR MWD030 units FT FT/H API Nsam Rep 1 68 1 68 1 68 Code Size 4 4 4 TLG013 3.000 9028.0 Flo-pro 8.70 55.0 9.0 30000 5.8 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 . .0 141. 0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9749 9985 9867 473 9749 9985 ROP MWD030 FT/H 0.75 62.91 29.8272 258 9856.5 9985 GR MWD030 API 15.08 766.66 39.0536 396 9749 9985 First Reading For Entire File..... .....9749 Last Reading For Entire File..... ......9985 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/08/04 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... ....05/08/04 Maximum Physical Record..65535 File Type.......... .. . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP GR $ 3 . header data for each bit run in separate files. 6 .5000 START DEPTH 9985.5 9985.5 STOP DEPTH 10020.0 9996.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... .............0 Data Specification Block Type.. ...0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units........ . . . Feet Data Reference Point.... '.' . . . . . . . . Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ....Undefined 05-DEC-04 Insite 8.01 Memory 10020.0 9985.0 10020.0 50.1 50.9 TOOL NUMBER TLG013 3.000 9028.0 Flo-pro 9.20 .0 9.0 86000 5.2 .000 .000 .000 .000 .0 141.0 .0 .0 . . Absent value..................... .-999 Depth Uni t s. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD060 GR MWD060 Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9985.5 10020 10002.8 70 9985.5 10020 ROP MWD060 FT/H 0.3 58.75 20.8563 70 9985.5 10020 GR MWD060 API 23.87 45.88 27.8657 23 9985.5 9996.5 First Reading For Entire File.. ........9985.5 Last Reading For Entire File...........10020 File Trailer Service name..... . ...... .STSLIB.003 Service Sub Level Name... version Number.......... .1.0.0 Date of Generation...... .05/08/04 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.......05/08/04 Maximum Physical Record..65535 File Type. .............. .LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 header data for each bit run in separate files. 7 .5000 START DEPTH 9997.0 10020.5 STOP DEPTH 10247.0 10271.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 05-DEC-04 Insite 8.01 Memory 10271.0 10020.0 10271.0 50.9 92.3 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG013 . . # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.000 9028.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo-pro 9.20 55.0 9.0 86000 5.0 .000 .000 .000 .000 .0 154.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............... .. .0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing...... . . . . . . . . . . . . . . .60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD070 MWD070 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9997 10271 10134 549 9997 10271 ROP MWD070 FT/H 2.88 103.89 52.0045 502 10020.5 10271 GR MWD070 API 21. 98 208.17 74.6203 501 9997 10247 First Reading For Entire File... .......9997 Last Reading For Entire File.......... .10271 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/08/04 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 service Sub Level Name.. . Version Number.......... .1.0.0 . Date of Generation.. .... .05/08/04 Maximum Physical Record..65535 File Type.... ........... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 . header data for each bit run in separate files. 8 .5000 START DEPTH 10247.5 10271.5 STOP DEPTH 11564.5 11591.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.. ...0 Logging Direction.................Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing................ .....60 .1IN Max frames per record. . . . . . . ..... . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . 08-DEC-04 Insite 8.01 Memory 11591.0 10271.0 11591.0 86.2 93.9 TOOL NUMBER TLG005 3.000 9028.0 Flo-pro 9.30 65.0 8.5 93500 5.0 .000 .000 .000 .000 .0 167.0 .0 .0 . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10247.5 11591 10919.3 2688 10247.5 11591 ROP MWD080 FT/H 0.01 1494.46 69.7471 2640 10271.5 11591 GR MWD080 API 43.09 199.2 86.1681 2635 10247.5 11564.5 First Reading For Entire File......... .10247.5 Last Reading For Entire File...........11591 File Trailer Service name..... ........STSLIB.005 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation.......05/08/04 Maximum Physical Recòrd. .65535 File Type................LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/08/04 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 6 header data for each bit run in separate files. 9 .5000 START DEPTH 11565.0 11591.5 STOP DEPTH 11704.0 11727.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 09-DEC-04 Insite 8.01 Memory 11728.0 11591.0 11728.0 86.7 90.0 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG013 # BOREHOLE AND CASING DATA . . OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.000 9028.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo-pro 9.20 55.0 9.0 93000 8.0 .000 .000 .000 .000 .0 171.1 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units......... . . Feet Data Reference Point............. . Undefined Frame Spacing........ .............60 .1IN Max frames per record.. ...... .....Undefined Absent value........ . .. " . . . . ..... -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD090 MWD090 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11565 11727 11646 325 11565 11727 ROP MWD090 FT/H 8.9S 370.35 74.905S 272 11591.5 11727 GR MWD090 API 25.93 200.53 71.0813 279 11565 11 704 First Reading For Entire File..... .... .11565 Last Reading For Entire File.......... .11727 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.......05/0S/04 Maximum Physical Record..65535 File Type.... ... ... ......LO Next File Name.... .......STSLIB.007 Physical EOF Tape Trailer Service name..... ... .....LISTPE Date.................... .05/0S/04 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.................... .05/08/04 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 . . Ä D vI ~I ~ c( $Revision: 3 $ LisLib $Revision: 4 $ Thu Aug 04 09:35:02 2005 1f n~~~ Sperry-Sun Drilling Services LIS Scan Utility Reel Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/08/04 Origin........... ...... ..STS Reel Name........ ........UNKNOWN Continuation Number..... .01 Previous Reel Name.......UNKNOWN Comments.......... .......STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date.................... .05/08/04 Origin. . . . . . . . . . . . . . . . . . .STS Tape Name................UNKNOWN Continuation Number..... .01 Previous Tape Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2-28a pbl 500292201270 BP Exploration (Alaska) Inc. Sperry Sun 04-AUG-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 MW0003410649 S. LATZ J. EGBEJIMBA MWDRUN 4 MW0003410649 B. JAHN B. HOLT / B. MWD RUN 5 MW0003410649 B. JAHN B. HOLT / B. # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 36 llN 14E 273 796 62.00 30.10 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.000 3.500 9028.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . . . 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE 2-28 WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 9832'MD/8733'TVDSS. 4. MWD RUNS 3 - 5 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. NO DRILLING DATA WERE ACQUIRED ON MWD RUNS 1 AND 2. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY RUN IN THE 2-28A WELLBORE ON 11 DECEMBER 2004. THESE LOG DATA WERE PROVIDED BY D. DORTCH (SIS/BP) ON 29 JULY 2005. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 3 - 5 REPRESENT WELL 2-28A PB1 WITH API#: 50-029-22012-70. THIS WELL REACHED A TOTAL DEPTH(TD)OF 11157'MD/8929'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...... .05/08/04 Maximum Physical Record..65535 File Type................LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9753.0 9857.5 STOP DEPTH 11136.5 11160.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9753.0 9761.5 9764.0 9766.0 9768.0 9769.5 9777.0 9779.0 9782.0 9790.5 9838.0 9839.5 9842.5 9844.5 9850.0 9855.0 9866.5 9877.0 9880.0 9886.0 9895.5 9902.5 9908.5 GR 9749.0 9757.5 9760.0 9762.5 9766.0 9768.5 9775.0 9778.0 9780.5 9790.0 9836.5 9838.0 9841.5 9843.0 9850.5 9854.0 9865.0 9875.0 9878.0 9886.0 9895.5 9900.0 9905.0 . . 9924.5 9935.0 9944.5 9949.5 9955.5 9958.0 9965.5 9970.5 9974.5 9980.5 9984.0 9986.5 11160.5 $ 9922.0 9932.5 9941. 5 9946.0 9953.0 9955.5 9963.0 9968.0 9972.0 9978.5 9981.5 9983.5 11157.5 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 3 4 5 MERGE TOP 9749.0 10400.0 10726.0 MERGE BASE 10400.0 10726.0 11157.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction... .......... ....Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Uni t s. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD GR MWD Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9753 11160.5 10456.8 2816 9753 11160.5 ROP MWD FT/H 0.01 305.67 45.2077 2607 9857.5 11160.5 GR MWD API 15.08 766.66 105.582 2687 9753 11136.5 First Reading For Entire File.... ......9753 Last Reading For Entire File.......... .11160.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation...... .05/08/04 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...... .05/08/04 Maximum Physical Record..65535 File Type......... .......LO Previous File Name...... .STSLIB.001 . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 3 .5000 START DEPTH 9749.0 9856.5 STOP DEPTH 10376.0 10400.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. ............... .Down Optical log depth units......... . . Feet Data Reference Point............. .Undefined Frame Spacing.....................60 .1IN Max frames per record.... ..... ....Undefined Absent value..................... .-999 Depth Uni t s. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT 01-DEC-04 Insite 8.01 Memory 10400.0 9856.0 10400.0 44.2 91.1 TOOL NUMBER TLG013 3.000 9028.0 Flo-pro 8.70 55.0 9.0 30000 5.8 .000 .000 .000 .000 .0 141. 0 .0 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 . . ROP MWD030 GR MWD030 FT/H API 4 4 1 68 1 68 4 8 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9749 10400 10074.5 1303 9749 10400 ROP MWD030 FT/H 0.75 88.18 43.3806 1088 9856.5 10400 GR MWD030 API 15.08 766.66 63.0856 1176 9749 10376 First Reading For Entire File......... .9749 Last Reading For Entire File...... .. .. .10400 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/08/04 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...... .05/08/04 Maximum Physical Record..65535 File Type. ........ .......LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 4 .5000 START DEPTH 10376.5 10400.5 STOP DEPTH 10702.0 10726.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 02-DEC-04 Insite 8.01 Memory 10726.0 10400.0 10726.0 89.0 93.8 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG005 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.000 9028.0 # BOREHOLE CONDITIONS . . MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo-pro 8.60 55.0 8.5 26000 6.8 .000 .000 .000 .000 .0 137.5 .0 .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.....O Logging Direction....... ...... ....Down Optical log depth units.......... .Feet Data Reference Point........ ......Undefined Frame Spacing........ .. ... ... .... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni t s. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD040 MWD040 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10376.5 10726 10551.3 700 10376.5 10726 ROP MWD040 FT/H 0.01 193.98 68.703 652 10400.5 10726 GR MWD040 API 52.63 210.23 102.131 652 10376.5 10702 First Reading For Entire File......... .10376.5 Last Reading For Entire File...........10726 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/04 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...... .05/08/04 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name.......STSLIB.003 Comment Record . FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 . header data for each bit run in separate files. 5 .5000 START DEPTH 10702.5 10726.5 STOP DEPTH 11133.5 11157.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. ................Down Optical log depth units.......... . Feet Data Reference Point............. .Undefined Frame Spacing............... ......60 .1IN Max frames per record. ... .. . .. ... . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD050 GR MWD050 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code 04-DEC-04 Insite 8.01 Memory 11157.0 10726.0 11157.0 84.7 94.0 TOOL NUMBER TLG005 3.000 9028.0 Flo-Pro 9.10 55.0 9.0 86000 6.8 .000 .000 .000 .000 .0 167.0 .0 .0 Offset o 4 8 Channel 1 2 3 .. . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10702.5 11157.5 10930 911 10702.5 11157.5 ROP MWDOSO FT/H 0.04 305.67 29.7272 863 10726.5 11157.5 GR MWDOSO API 111.27 203.59 165.674 863 10702.5 11133.5 First Reading For Entire File......... .10702.5 Last Reading For Entire File.......... .11157.5 File Trailer Service name......... ... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......OS/08/04 Maximum Physical Record..6SS3S File Type................LO Next File Name.......... .STSLIB.OOS Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/08/04 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.................... .05/08/04 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
