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205-122
1 Gluyas, Gavin R (OGC) From:Wallace, Chris D (OGC) Sent:Wednesday, January 15, 2025 8:25 AM To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector W-17A (PTD #2051220) will lapse on AOGCC MIT-IA From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 14, 2025 4:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector W-17A (PTD #2051220) will lapse on AOGCC MIT-IA Mr. Wallace, Injector W-17A (PTD #2051220) is due for its 4-year AOGCC MIT-IA by the end of January 2025. It is currently shut-in with no plans to have it online before the end of the month. The well is now classified as NOT OPERABLE for tracking purposes. Please respond with any quesƟons. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. 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 have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023W-17A 205122 500292185601 3 9/23/2023 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 11e�7� ;� DATE: Thursday, January 21, 2021 P.I. Supervisor f �n 1�I2trLl SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC W -17A FROM: Lou Laubensteln PRUDHOE BAY UNIT W -17A Petroleum Inspector Src: Inspector Reviewed By%p�r P.Supry �t�- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT W -17A API Well Number 50-029-21856-01-00 Inspector Name: Lou Laubenstein Permit Number: 205-122-0 Inspection Date: 1/17/2021 ' InSp Num: mitLOL210118170139 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W -17A Type Inj I W 'TVD 4858 Tubing 10921092 1092 1092 PTD 2051220 " Type Test SPT Test psi 1500 IA 262 1807 1788 1780 ' BBL Pumped: 12.2 BBL Returned: 2.2 OA 140 140 - 141 142 Interval 4YRTST PIF P Notes: Good test, no issues. ' Thursday, January 21, 2021 Page 1 of I 110 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 205-122 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service f31 6. API Number: 50-029-21856-01-00 7. Property Designation(Lease Number): ADL 0047451 8. Well Name and Number: PRUDHOE BAY UNIT W-17A 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 12500 feet Plugs measured feet RECEIVED true vertical 9051 feet Junk measured feet APR 2 0 2 017 Effective Depth: measured 12411 feet Packer measured 5681 feet true vertical 9036 feet Packer true vertical 4859.17 feet r CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 37-117 37-117 Surface 2819 13-3/8"68#N-80 36-2855 36-2688 5020 1140 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10570-10600 feet 10600-10630 feet 10630-10660 feet 10660-10690 feet 10690-10720 feet 10720-10750 feet 11320-11755 feet 11825-12080 feet True vertical depth: 8939-8954 feet feet 8954-8968 feet 8968-8983 feet 8983-8996 feet 8996-9009 feet 9009-9020 feet 9019-8941 feet 8940-8980 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 32-5738 32-4908 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED MAY 15 2017 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1706 520 1023 Subsequent to operation: 1540 760 1043 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations IBJ Exploratory 0 Development 0 Service filf Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG I3 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 Authorized Name: Peru,Cale Contact Name: Peru,Cale Authorized Title: Petroleum E eer Contact Email: Cale.Peru@bp.com Authorized Signature: ( Date: y!/20I /7 Contact Phone: +1 9075644522 Form 10-404 Revised 04/2017 YTL 51/d //9- 40,74,�B DMS L, f,d::? — 3 2017 Submit Original Only • m a O O O o 0 0 0 .cr- N- N OOo - � r� r� v Lo Ln O LO 1- 1"-- C.)U N 0 0 0 0 Co 0 0 L N f� I- CO CO CO O 00 00 N d m LO CO CO N CO CO CO CO CO CO CO CO CO CO CA O O) O LO O CO O LO O) N N cr CO CO O) Cl I I I I I I I H O) CO I� CO V o) CO O) O) N CO CO CO O N CO CO CO N d" V CO ++ Q NorO Cfl O LO CO d M (A O co — coM to • N N to 0 00 tf) cc• I-- 4-0 Z - z QLO N I� CO co CO N N CO CO M A-- C) I- CO N V' In • W O 0 0 0 OO O O CO 00 CO CO OO CO CO T U z J J 00 J J J C d -00 co 1I.. *k J CO CO CO N LL O tea bM �j �j � NNN N O , i , O O) O • O (N a, O c0 co co 't M N- J N N CO LO V N Ln W � Q Q CO 0• Woo •NUUww Q �oD2 C7 O a Li_ cc Q ecc z zwwwwwm p D 1— H z z z_ D U Cn Z Z J J J • Packers and SSV's Attachment PRUDHOE BAY UNIT W-17A SW Name Type MD TVD Depscription W-17A PACKER 4946.6 4289.86 7" Baker ZXP Top Packer W-17A TBG PACKER 5680.92 4859.17 4-1/2" Baker S-3 Perm Packer W-17A PACKER 5734.98 4906.02 5" Baker ZXP Top Packer W-17A PACKER 10181.6 8692.58 5" Baker ZXP Top Packer • • Ot 400 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary April 20, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for W-17A Add Perforations work performed in March 2017. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • 0 0 % . L G a G . % \ \ E _/ / / / / ƒ _/ F- a \ \ \ " = \ c I I Z I I III O H 0 o_ o_ F- 0_ Z L 0000 \ did / d / dh E Z Q Z E 2 Z I Z 2 0 E R k % / / / 10)1 \ / ƒ % 0 / / / / � � 0 0 0- _I0- / E 0000 / � / � � CI ) CI ® 0 - o / 000ek E2242 \ 2 \ 2 � ƒ m LIUUH0 I < � ' rm � II � / k § Qy c ƒ / % / o k ƒ w � 0 ® % / % ® 0 m M 7 ƒ ƒ / a F- 0 / 0 / D (DO (0 F © O © F- / / / / k E 0 / o o R ± % \ 0. w6moI / ® / ® I � f / iiO � � �� x x 2 U L 0 O % m w / 7 / 7 / E / � \ / kL IGI ) / 71-) % / � \ w / $ \ \ R / 6E / / / / E \ + < � l -3 -) L : 9 � \ \ / % � � ® � 0 0 o / E / E / &_ ƒ < E e b _' Et \ E ƒ rW p $ $ R $ 2 / 3 2 ± % c / / � m � L 0 o % r $ o 2 a) 0 / / / ' - ti 0 0 < / ƒ / � M " \ � E % \ 3 � � � � / � % / / U0 (N (N \ \ ƒ >< 0 / / M il 6 < X W X W WO 0 Z x u x HW ^ E ^ L 0 / : 0 Z \ ZO wp DOoZoZ \ z / / _ / / W I - - $ k / o _n - _n - r _ r 0 / 2 CZ E > E \ / EZ Z k / / W / / II < IRIR2 \ - 2 J J = \ 7 0 0 2 / J r ƒ ƒ / / J Z / 2 O c / 4L & E \ Ui / E E ƒ A / 4U- G / G ? } \ \ I ) EDEDE \ / E / / ffEfE DEDW \ / / / \ : % r2C 12 I I cNI : : O °- °- E I E < 0 3 : 0 L < N- N. 0\ / \ m 2 CO \ / � 0 n r < TREE= 4-1/16" • WELLHEAD= MCEVOY I SA Y NOTES: H2S READINGS AVERAGE 125 ppm ACTUATOR= OTIS VV-17A -17A WHEN ON MI.WELL REQUIRES A SSSV WHEN ON KB.ELEV= 81.62' ML WELL ANGLE>70"@ 10771'. BF.ELEV= 53.71' KOP= 1484' Max Angle= 102°@ 11199' 2219' 4-1/2"HES X NP,D=3.813" Datum MD= 11465' Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347' —) 2854' , GAS LFT MANDRELS ST MD TVD DEV TYPE' VLV LATCH PORT DATE ' 2 3560 3223 40 KGB2 DMY BK 0 09127108 9-5/8"x 7"BKR ZXP LNR TOP PKR& ! 4933' L_ 1 1 5590 4782 34 KGB2 DMY BK 0 09/27/08 BKR FLEX LOK LNR HNGR,D=6.30" CMT PLUG H 5036' I 1 �5 i♦ I� TOP OF MILLOUT 9-5/8" 9-5/8"CSG,47#,L-80,D=8.681" H -5240 '"N WINDOW 5240' • ' ,-- `5658' I--4-1/2"HES X NP,D=3.813" Minimum ID = 3.725" @ 5723' 4-1/2" HES XN NIPPLE S 5679' }-7"X4-1/2"BKR S-3PKR,D=3.875" ' ' 5702' 1—4-1/2"HES X NP,D=3.813" 5721' E—7"X 5"BKR ZXP LTP&BKR FLEX LOCK HGR,D=4.390" 11 I' ►4 5724' —4-1/2"HES XN NP,D=3.725" 14-1/2"TBG, 12.6#,L-80 TCI,.0152 bpf,D=3.958" —1 5736' .a 0 ►♦♦ w ♦04 ♦ 5736' —4-1/2"WLEG,D=3.958" ►♦♦ ♦ ♦ 4 j♦j ♦ —B.MD TT NOT LOGGEDI ,�, 5749' I—5"X 4-1/2"XO,D=3.96" • • 4-1/2"TEBACK LNR 12.6#,L-80 —I 10181' A• ♦• BT-M,.0152 bpf,ID=3.958" �♦� ♦ 10172' —4-1/2"HES ORFICE FLOAT 11 ♦� •♦ COLLAR,ID=3.93" ►♦� _ 10181' 4-1/2"X 5"XO,D=4.35" 7"LNR,26#,L-80 BTC-M,D=6.276" — 10330' ► 01 P 10184' H 5"BKR TEBACK STEM SEAL ASSY 21 FERFORA11ON SUMMARY 1 1 w/NO-GO COLLAR,D=4,35" REF LOG:SWS MDL VISION RESISTIVITY ON 09/19/05 10179' —7"X 5"BKR ZXP LTP& ANGLE AT TOP FERE:610 @ 10570' FLp(LOCK HGR, D=440" Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 102Q7' —5"X 4-1J2"XO, D=3.95" 2-7/8" 6 10570-10690 0 03/27/17 , 2-7/8" 6 10690- 10750 0 03/26/17 ' 2-7/8" 4 11320-11755 0 10/01/05 , 2-7/8" 4 11825- 12080 0 10/01/05 I PBTD —I 12412' I 4-1/2'LNR,12.6#,L-80 BT,.0152 bpf,D=3.958" 12498' •••♦ DATE REV BY COM'VENTS DATE REV BY COM E TTS FRUDHOE BAY UNfT 9/88 • ORIGINAL COMPLETION 02/16/11 MB/JMD ADDED SSSV SAl-ElY NOTE WELL: W-17A 10/16/90 JQ ORIGINAL COMPLETION 07/29/11 CJK/PJC FERE REF LOG UPDATE PERMIT No:' 051220 10/03/05 WES 'SIDETRACK(W-17A) 01/20/12 TM'YJM) ADDED H2S SAFEI Y NOTE - API No: 50-029-21856-01 10/27/05 KSB/TLH GLV GO 03/29/17 NXW/JMD ADFH2FS(03/26-27/17) SEC 21,T11N,R12E,766'FNL&1183 FEL 12/02/05 MJAITLH DRLG DRAFT CORRECTIONS — 10/17/08 SEW/PJC GLV GO(09/27/08) BP Exploration(Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg DATE: Tuesday,January 10,2017 P.I.Supervisor 1<<'7 j I f(z it 7 SUBJECT: Mechanical Integrity Tests l BP EXPLORATION(ALASKA)INC. W-17A FROM: Chuck Scheve PRUDHOE BAY UNIT W-17A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry }�5�-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT W-17A API Well Number 50-029-21856-01-00 Inspector Name: Chuck Scheve Permit Number: 205-122-0 Inspection Date: 1/9/2017 Insp Num: mitCSI70110061118 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W-17A Type Inj W 'TVD 4858 Tubing 1284 1275 1266 1260 PTD 2051220 ' Type Test SPT Test psi 1500 IA 463 • 2185 2154 - 2145 BBL Pumped: 'BBL Returned: OA T 177 -•I 177 - 177 - 178 - Interval : 4YRTST P/F P ✓ Notes: O1iF,p AFTtL 7 Tuesday,January 10,2017 Page 1 of 1 Image Project Well History Fite Gover 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. o~OJr- ~ ~ ~ Well History File Identifier Organizing (done) RESCAN ~j Color Items: ~Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: ~.„~-,dam NIIIIIIIIIIIIIIIII DIGITAL DATA ~skettes, No. ^ Other, NolType: ae,v~~,~d~ iiiuiiiiAiiuuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: ~ Maria Date: ~, ~' ~ ~ ~ /s/ V 1 ~i I Pro "ect Proofin ~ II I II III II II V III -- J g BY: aria Date: ~, ~ ~ /s/ , Scanning Preparation ~~ x 30 = ~_ + ~ =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: ~ ~ D g /s/ ~~ Production Scanning Stage 1 Page Count from Scanned File: ,~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: _~YES NO BY: Maria Date: a, ~ ~ ~ ©g /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: !s/ I Scanning is complete at this point unless rescanning is required. II I II II II ~ II II ~ I III ReScanned III II~IIIIIIII (IIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III III II'I III 10/6!2005 Well History File Cover Page.doc OPERABLE: W-17A (PTD #20512) Mitigated OA Repressurization Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, January 22, 2009 7:37 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad SW; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr Cc: Robertson, Daniel B (Alaska); Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: OPERABLE: W-17A (PTD #2051220) Mitigated OA Repressurization All, As part of the PPPOT-iC on well W-17A (PTD #2051220), the wellhead seals were serviced. Servicing the seals restored integrity proven with a passing PPPOT-IC and a passing OA repressure test. The well has been reclassified as Operable. ,/A recent TIO plo# has been included. The high IA pressure shown on the plot is due to the OA repressure test where pressure is applied to the IA and the OA pressure is monitored. Please let me Know if you have any questions. Thank you, Anna ~Du6e, 2'. E. Well Integrity Coordinator GPB Weils Group Phone: (907} 659-5102 Pager: (907} 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, January 11, 2009 2:18 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GP6, GC2 Wellpad Lead; GPB, Well Pad SW; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr Cc: Robertson, Daniel B (Alaska); Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: W-17A (PTD #2051220) OA Repressurization -UPDATED PLAN All, ft has been decided that MI injection is vital to pattern health and an AA might not be the best plan €orward. The new plan forward for the well is as follows: 1. W: PPPOT-IC 2. APE: Eval for TecWel LDL The well is on day 14 of the 28-day clock as of today, 01/11/09. Please call with any questions or concerns. Thank you, 1 /27/2009 OPERABLE: W-17A (PTD #2051) Mitigated OA Repressurization Page 2 of 2 • Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, December 29, 2008 2:12 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad SW; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr Cc: Robertson, Daniel B (Alaska); NSU, ADW Well Integrity Engineer; Townsend, S. Eliot Subject: UNDER EVALUATION: W-17A (PTD #2051220) OA Repressurization All, Well W-17 (PTD #2051220). is a WAG well currently on produced water injection with likely IAxOA communication. Since the well was put on water injection at the end of October, the OA pressure has been elevated at --700 psi. It was thought to be thermal because both the IA and OA fluid levels are at surface; the last AOGCC witnessed MIT-IA passed to 4,000 psi on 10/31/08. However, the IA increased to approximately OA pressure after it was bled to 290 psi on 12/26/08. Annulus gas samples were obtained and found the IA and OA gas to very similar. The well has been reclassified as Under Evaluation for further diagnostics. The plan forward for the well is as follows: 1. D: Bleed OAP to 0 psi, quantify build up rate 2. WIC: Send AA request A TIO plot, injection plot and wellbore schematic have been included for reference. In addition, I have included the gas sample results. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 1 /27/2009 • ¢ m ¢o ~ ¢oo c ~doooo 1~ ~~~ ~~ r~ r T 0 0 '~`~. 0 T L~ 0 '\~ n~ O ^~. r 0 r~ O "~ r~ t~~ -,,. c~a r ii? ~~ '~ O _ N ~_ t~l r f~l Q "a. M r N tL1 L ry 0 -~._ N T r~ 0 ~T 4~ '^~. f r 4~} "~. N ry z. T Q 0 1, LL7 T ^+~ T f O Zti a r-, r r-, ~~ ~ ~,. a X l '~ '~ ~ -ti N ~ ° ~ 3 N n ~ ° o a a I ; t UNDER EVALUATION: W-17~'TD #2051220) OA Repressurization • Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~ ~' + '1~ c I ~'~ 1 Sent: Monday, December 29, 2008 2:12 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad SW; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr Cc: Robertson, Daniel B (Alaska); NSU, ADW Well Integrity Engineer; Townsend, S. Eliot Subject: UNDER EVALUATION: W-17A (PTD #2051220} OA Repressurization Attachments: W-17A TIO and Injection Plots.doc; W-17A.pdf; W-17 Townsend IA&OA.dot All, Well W-17 (PTD #2051220) is a WAG welt currently on produced ~er~ter injection with likely IAxOA communication. Since the well was put on water injection at the end of October, the OA pressure has been elevate at --700 psi. It was thought to be thermal because both the IA and OA fluid levels are at surface; the last AOGCC witnessed MIT-IA passed to 4,000 psi on 10/31108. However, the IA increased to approximately OA pressure after it was bled to 290 psi on 12/26/08. Annulus aas samples were obtained and found the IA and_OAs~as to very similar. The well has been reclassified as Under Evaluation for further diagnostics. The plan forward for the well is as follows: 1. D: Bleed OAP to 0 psi, quantify build up rate 2. WIC: Send AA request .,--- A TIO plot, injection plot and wellbore schematic have been included for reference. In addition, I have included the gas sample results. «~/~/-17A TIO and Injection Plots.doc» «W-17A.pdf» «W-17 Townsend IA&OA.dot» :/ Please call with any questions or concerns. Thank you, Andrea Hughes ~i"~~Y'~~~=~` ~i~~,, :i. f~ ~QG Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 • PBU W-17A PTD 205-122 12-29/2008 TIO Pressures ~1 ~~ ~' ~ ~xl onlrDe uJ!it+,u la!:~a 11tOltrJ<i 11/08t[~ nns!oe nr2z!r~s nr~:•~ 1_•nF'!2 un~,~ 12/~OfQB 1~2noe ~ Injection Rate 1.~3J 1.~J 1,1U 1 r~bl t~l 1,Ab] 1.~) 1.2>Dl 1 1 DJ a t.rfi] ~. 7Dr1 h~7D lrp7 :YFI 3 (Cu ~~ ? E(Cl 2,4Q1 ?. lJ w <8~1 15iCi ~ ' t~~0 r 1 4(M n l .~Yl 1,OllO SOD r~(jl 4C0 :~1' D%Odi[5 _ ~._ iP07/O8 11JOB,~ki li!15!OS 11!'hU6 77!al~tw 1 - fio l~rl;!OD 122UAJ8 1!2i!OS • I -*- rn~ ~ -f_ ~ i Oan -+ oooa 'I ~ Dn -WHIP - ~t - PW MI - GI - ONin . On • GPB LAB ORA TOR Y ANAL YTICAL REPOR T 907-659-5654 Email: GPIiL,ab(c%~bj~.COm ,.~ i,~1 ~- - ~ A P~ z~~ -i ~Z Sample ID Collection Date Facility Well Location Analysis Name LINE PRES METHANE-MOL% ETHANE-MOL% PROPANE-MOL% I-BUTANE-MOL% N-BUTANE-MOL% I-PENTANE-MOL% N-PENTANE-MOL% C6P-MOL% C02-MOL% NITROGEN-MOL% MOL WEIGHT BTU GRSDRY IDEAL BTU GRSDRY REAL BTU GRSSAT IDEAL BTU NET SPG REAL 02 CONTAM Analysis Unit PSIG MOL% MOL% MOL% MOL% MOL% MOL% MOL% MOL% MOL% MOL% BTU@14.696PSIA BTU@14.65 PSIA BTU@14.73 PSIA BTU@14.696PSIA MOL% PC25234 12/26/08 W-PAD W-17 OA Combination Result 740 81.194 5.370 2.201 0.366 0.427 0.094 0.118 0.140 9.556 0.534 20.711 1012.0 1011.6 996.7 914.1 0.7168 0.004 PC25235 12/26/08 W-PAD W-17 IA Combination Result 400 88.134 7.398 2.367 0.349 0.414 0.070 0.083 0.071 0.593 0.521 18.435 1115.3 1114.8 1098.4 1007.8 0.6380 0.062 DISTRIBUTION Eliot Townsend Reported by: at 10:22 AM on 01/05/09 TREE= 4-1/16" AD WELLH E MCEVOY _ _ ACTUATOR m OTIS1 KB. ELEV = 81.62'' BF. ELEV - 53.71' KOP = ~ ~ 1484' Max Angle = 102 @ 11199' Datum MD = 11465' Datum TV D = 8800' SS ', 13-3/8" CSG. 72#, L-80, ID = 12.347" ~ 2$54' Minimum ID = 3.725" @ 5723' 4-112" HES XN NIPPLE CMr PLUG I-) 5x36' Ezsv 5599' TBG STUB -(- 7$~$' P&A -~ 11 aaa' r 9-5/8" CSG, 47#, L-80, ID = 8.681" 11417' 7" LNR, 26#, L-80, IJ4S, iD = 6.276" 11973' 4-112" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" PERFORAT{ON SUMMARY REF LOG: ?7'?? ON ANGLE AT TOP PERF: 101 @ 11320' Nate: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnJSgz DATE 2-718" 4 11320 - 11755 O 10!01105 2-718" 4 11825 - 12080 O 10(01105 ~~~ ~A NOTES: 2219' I-i 4-112" HES X NIP, fa = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 3560 5590 3223 4782 40 34 KGB2 KGB2 DMY DMY BK BK 0 0 09/27/08 09!27!08 4933' ~--I9-5/8" x 7" BKR ZXP LNR TOP PKR & BKR FLEX LOK LNR HNGR, ID = 6.30" TOP OF MILLOUT 9-5/8" WINDOW 5240' 5658' 4-112" HES X NlP, ID = 3.813" 5679' 7" X 4-1/2°' BKR S-3 PKR, ID = 3.875" 57a2' 4-112" HES X NIP, ID = 3.813" 5721' 7" X 5" BKR ZXP LNR TOP PKR &BKR FLEX LOK LNR HNGR, 1D = 4.390" 5724' 4-1(2"-HES XN NIP, ID = 3.725" 5736' ~-I4-112" WLEG, ID = 3.958" ELMD TT NOT LOGGED 5749' S" X 4-1 i2" XO, ID = 3.96^ 1x172' 4-112" HES ORIFICE FLOAT COLLAR, ID = 3.93" 101$1' 4-112" X 5" XO, ID = 4.35" 10184' 5" BKRTIEBACK STEM 5736' SEAL ASSY wf NO-GO COLLAR, ID = 4.35" 10181' 10179' 7" X 5" BKR ZXP LNR TOP PKR & FLEX LOK LNR HNGR, ID = 4.40" 10207' S° x 4-112^ xo, ID = 3.95" ~4-112" TIEBACK LNR 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" ~ 7" LNR, 26#, L-80 BTGM, !D = 6.276" ~-~ 1 a33a' PBTD 12412° 4-112" LNR, 12.6#, L-80 IBT, .0152 bpf, ID = 3.958" 1249$' DATE REV BY COMMENTS DATE REV BY COMMENTS 9/88 ORIGINAL COMPLETION _____ 10/16/90 JQ ORIGINAL COMPLETION 10/03105 N7E5 SIDETRACK (W-17A} 10!27/05 KSBtTLH GLV CIO 12/02/05 MJAITCH DRLG DRAFT CORRECTIONS 10!17108 SEWIPJC GLV CIO {09127!08) PRUDHOE BAY UNfC WELL: W-17A PERMf~ No: 2051220 API No: 50-029-21856-01 SEC 21, T11N, R12E, 766' FNL & 1183' FEL BP Exploration (Alaska} STATE OF ALASKA v r ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERA~'Y(~f~~~~~~ `~-~`~`~~ r/ ,a•v~3 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ "Stirt)ui~fe~ Other ~ CONV'T TO Performed: Alter Casing ~ Puli Tubing Perforate New Pool ~ Waiver :Time Extension INJECTOR Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~lopment ~ Exploratory ` ~ 205-1220 - 3. Address: P.O. Box 196612 ` Stratigraphic ~ Service I 6. API Number: Anchorage, AK 99519-6612 50-029-21856-01-00~ 7. KB Elevation (ft): 9. Well Name and Number: 84.56 KB PBU W-17A - 8. Property Designation: 10. Field/Pool(s): ADLO-047451 PRUDHOE BAY Field/ PRUDHOE BAY Pool 11. Present Well Condition Summary: Total Depth measured 12500 feet Plugs (measured) None true vertical 9051.01 - feet Junk (measured) None Effective Depth measured 12411 - feet true vertical 9036.48 - feet Casing Length Size MD TVD Burst Collapse Conductor 110 20"91.5# H-40 31 - 141 31 - 141 1490 470 Surface 2824 13-3/8"68# L-80 30 - 2854 30 - 2686 4930 2270 Production 5211 9-5/8" 47# L-80 29 - 5240 29 - 4506 6870 4760 Liner 5397 7" 26# L-80 4933 - 10330 4280 - 8796 7240 5410 Liner 6777 4-1/2" 12.6# L-80 5721 - 12498 4894 - 9051 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 26 - 5736 0 0 - Packers and SSSV (type and measured depth) 9-5/8" BKR ZXP TOP PKR 4933 7" BAKER S-3 PKR 5679 7" BKR LNR TOP PKR 5721 7" BKR ZXP LNR TOP PKR 10179 12. Stimulation or cement squeeze summary: Intervals treated (measured): ,~, ~ ~yp1yy~ ~~ kh`i~.;,. ,_ ~~ n Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 2390 1732 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~' ~ GINJ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-341 Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 11/10/2008 Form 10-404 Rev~04/2006 ~ ~ ~ - Submit Original Only ~,\~ W-17A 205-1220 PFRF ATTArHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base W-17A 9/21/05 PER 11,320. 11,755. 9,019.48 8,940.96 W-17A 9/21/05 PER 11,825. 12,080. 8,939.82 8,979.61 APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • . • • W-17A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY I 10/31/2008`: T/I/0=1650/1650/650. Temp=Hot. AOGCC MITIA PASSED to 4000 psi °.' (post-Initial Injection). State witnessed by Chuck Schev_e. IAP decreased 40 °. psi in 1st 15 mins, 10 psi in 2nd 15 mins, for a total of 50 psi in 30 mins. LRS in control of well upon departure. 10/31 /2008 ~_._ T/I/0=1650/1650/650 Temp=Hot MIT IA PASSED to 4000 psi. (AOGCC witness by C.Sheve) Pumped 3 bbls methanol into IA to reach test pressure. IA lost 40 psi in 1st 15 min and 10 psi in 2nd 15 min for a total loss of 50 psi in 30 min. Bled IA (~ 5 bbls). FWHP's=1650/400/650. Annulus casing valves tagged and left open to gauges. Well on injection and DSO notified of valve positions upon departure. FLUIDS PUMPED BBLS 3 METHANOL 3 Total MEMORANDUM To: Jim Regg ~ „~ l ~ ~ id~ t}~ P.I. Supervisor "`~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, Novemher O5, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) IIQC W-17A PRUDHOE BAY UNIT W-17A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UNIT W-17A API Well Number: 50-029-2 1 8 5 6-0 1-00 Inspector Name• Chuck Scheve Insp Num• mitCS081102111113 Permit Number 205-122-0 ,/ Inspection Date: 10/31/2008 Rel Insp Num: Packer Depth Pretest In itial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ W-nA iType Inj. ! ~' IW VD -- p Z. zostzzo ~TypeTest SPT Test psi ~4858 IA ~--- ~ Isoo pA ~ - ,660 4000 - 6so ~ 6so X 3960 3950 I --1 - ~ --- 6so 6so -~ - Interval iNrTAL '/ P/F P _ '' Tubing I6so ~so ~ _ I6so ~ I6so Notes: ~~ ~-~~- 5 ~ Z- l 44~~ ~'B ~ ~ Wednesday, November O5, 2008 Page 1 of 1 • • ~~~~~ ALASSA OIL AKD GAS COI~SERQA'1`IO1~T COriM15SIOrIT Daniel Robertson P.E. SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 BP Exploration Alaska. Inc. PO Box 196612 ~ ~,/ I ~Z Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU W-17A Sundry Number: 308-341 Dear Mr. Robertson: roved A hcation for Sundry Approval relating to the Enclosed is the app PP 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 iri 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 date of this ldetterelor thelnext w° lung 4:30 PM on the 23rd day following the day if the 23rd day falls on a holiday or w u~ u es s rehearing has been a Commission decision to Supenor Co requested. Sincerely, /o\~'~ ~6 Daniel T. Seamount, Jr. Chair DATED this ~ ~ day of October, 2008 Encl. by • • ~~ 4S BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 89519-6612 (907)561-5111 September 22, 2008 Tom Maunder Alaska Oil & Gas Conservation Commission '~ 333 West 7'" Avenue Suite 100 ~ `v Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for W-17a Conversion from Producer to Injector Exploration Alaska, Inc. proposes to convert well W-17A from ashut-in producer to a WAG injection well as part of the Eileen West End Flood Development project. Well W-17A was sidetracked to the current bottomhole location October 2005. The well was pre-produced intermittently for 14 months, until it was no longer competitive relative to other wells due to low oil rate and high watercut. It has been shut in since that time. It is now planned to proceed with conversion to injection to provide pressure support, waterflood and miscible gas injection sweep for the area. The forward plan for conversion of well W-17a is attached along with an area of review for offset wells. Please contact Dan Robertson at 564-5546 with any questions or comments. Sincerely, G~-~~- Daniel B. Robertson, PE Senior Petroleum Engineer Well W-17a Current Status: No pressure testing has been performed since the 2005 completion, but the well was completed with premium thread tubing and has had relatively little production since the initial completion. There is no data which would indicate a lack of well integrity. Plan Forward: 1. Obtain static pressure survey, install dummy gas lift valves. 2. MIT~1A at 2500 psi, step rate injection test. 3. Place well on water injection (confirm AOGCC approval prior to injection, target and maximum injection rates TBD by step rate test) 4. AOGCC witnessed MITIA at 2500 psi after injection stabilized. :. s ' . ,~ • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~n AAC ~s ~Rn 1. Type of Request: Abandon Suspend Operational shutdown Perforate Alter casing^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ^ convert to injector Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development , Exploratory ^ 205-1220 - 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21856-01-00 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 W-17A ' Spacing Exception Required? Yes ^ o ^ 9. Property Designation: ~ 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-047451 ~D~Opa~o?(,3 84.56 KB ~ PRUDHOE BAY Field / PRUDHOE BAY Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12500 ~ 9051.01 12411 - 9036.48 ' NONE NONE Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 20" 91.5# H-40 31 141 31 141 1490 470 SURFACE 2824 13-3/8" 68# L-80 30 2854 30 2686 4930 2270 PRODUCTION 5211 9-5/8" 47# L-80 29 5240 29 4506 6870 4760 LINER 5397 7" 26# L-80 4933 10330 4280 8796 7240 5410 LINER 6777 4-1/2" 12.6# L-80 5721 12498 4894 9051 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# L-80 26 - 5736 Packers and SSSV Type: 9-5/8" BKR ZXP LNR TOP PKR Packers and SSSV MD (ft): 4933 7" BAKER S-3 PACKER 5679 ~-- 7" BKR LNR TOP BKR 5721 7" BKR ZXP LNR TOP PKR 10179 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/7/2008 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ~ ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Daniel Robertson Printed Name Daniel obertson Title P.E. Signature Phone 564-5546 Date 9/23/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: - ~F\\ es ''_ ~( Plug Integrity ^ BOP Test ^ Mechanical Integrity Test {~ Location Clearance ^ `y ~`~ IT ~ S~ s~~~~'~lo~ 1~_^ f Other: ~ `~~~`^G~ dp`C1-t4-~~~t~S~~t~ ~' CC ~~~ ~ ~ ~ © ~~ d / Subsequent Form Required: I~Q APPROVED BY ~ I ~ / ~~ Approved by' ~ COMMISSIONER THE COMMISSION Date: / v ~. - _,~ - y~S~~ "~,;_ ~ a•~~ Waiver ^ Othe Form 10-403 Revised 06/2006 ~ ~ ^ ~ ~~ A ~ ~-~~" ~.~~ ~"~, 1)i, f ~ % ~QQQ Submit in Duplicate W-i 7A 205-1220 PF_RF ATTA(:HMFNT • Sw Name Operation Date_ ~ Perf Operation Code ~eas Depth Top Meas Depth Base I Tvd Depth Top Tvd Depth Base W-17A _ 9/21/05 PER ___ 11,320. __ 11,755.1 ______ 9,019.48 _ 8,940.96 W-17A 9/21/05 PER 11,825. 12,080. 8,939.82 8,979.61 APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED _ SL SLOTTED LINER _ BPS BRIDGE PLUG SET _ _ SPR SAND PLUG REMOVED FCO FILL CLEAN OUT _ SPS SAND PLUG S ET FIL FILL __ SQF _ SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED __ STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE __ _ • • Area of Review - W-17A Revised September 22, 2008 ~~3-~oc~ ~0~ - l t 1 This Area of Review for W-17a will discuss the wells that are within 1/a mile of this injection well BHL (see figure 1 below). W-17a is proposed as a WAG injection well in the Ivishak reservoir. There are three wells that come within '/a mile of W-17a bottomhole location at the top Ivishak. The following table displays the 3 wells within 1/a mile, their distance from W-17i, and any annulus integrity comments based on an in depth analysis of each well: (~~ CaSSrCSS ~Cc~~ ~ v~+c-i-1C. ~~Z 4~ i Well Name Dist, Ft. Annulus Inte rity Comments W-16A 1197' (from heel) TOC calculated to be above in'ection zone. W-21A 1007' (from heel) TOC calculated to be above injection zone. W-15A 886' (from toe) TOC calculated to be above injection zone. In well W-17A, a 4'/2" liner was run to 12498' and hung off at 10179'. It was cemented with 60 barrels of cement with no recorded loses. 20 barrels were circulated off the top of the liner. No cement bond log was run in the 4.5" liner. A 7" liner was run to 10330' and hung off at 4933'. It was cemented with 183 barrels and 20 barrels of cement were circulated off the top of the liner with no recorded loses. A USIT type cement bond log was run inside the 7" casing. It showed 650' of competent cement from 10150' (above 4.5" liner lap) up to f approximately 8500' and partial cement from 8500' to the top of the liner. A rig cement squeeze was performed to provide better zonal isolation across the Schrader bluff sands; a 5" tieback was run to isolate squeezed perforations. Cement bond logs are not available for W-21 A, W-15A, and W-16A, so cementing records were reviewed for these wells. In well W-15A, a 7" liner was run to 11974' and hung off at 11336'. It was cemented with 41 barrels of cement. The TOC was calculated based on the cement volumes pumped with 30% excess in the annular space. No losses were noted. In well W-16A, the 9 5/8" casing was run to 10805' and hung off at surface. It was cemented with 424 barrels of cement. The TOC was calculated based on the cement volumes pumped with 30% excess in the annular space. No losses were noted. In well W-21A, a 7" liner was run to 10085' and hung off at 9155'. It was cemented with 43 barrels of cement. There were no reported losses during the ~~~c ~ • • cementing job. There was no discernable cement in the returns, but there was a very distinct cement odor in returns at surface, presumably indicating the cement returned above the liner top but perhaps got diluted being circulated to surface. 000 Bt6.000 616.000 • 620.000 8. I I I O W EE ~~ a 8 6 W 1 - 1 ~e 8 ~~~ - 7AHEEL 98 49 ~ Elfin i.~ 5.96: S. 96f 5.95E 1 `~ 5.95E sf~.eee sfs.eae sfe.eee sze.eea ezz.eee KILOIETE119e~s K]LOIIETEAS '¢T a ~ rt[T uTKTYT! NILlf ~ 71KTUT! N1U! Figure 1. W-17a Area Bottomhole Location Area Map, 1/a mile radius circle centered on the top Ivishak penetration Wells W-16a and W-21a are within'/a mile of W-17a at the heel of W-17a. Well W- 15a is within ~/a mile of W-17a toward the toe of W-17a. 8~ • To: Clark Olsen/ Jerry Bixby Well Operations Team Leader From: Dan Robertson, PE Date: September 23, 2008 Subject: W-17a Iniection Conversion Slickline, MITIA, Iniection Test Est. Cost: $50M Sundry Approval #: pending Cost Code: PBWPDWLI7-C It is planned to convert W-17a to WAG injection service. The well will be placed on water injection for a few months initially, then swapped to MI injection. Please proceed with the work to prepare for injection, but do not place the well on injection until AOGCC approval is received. The objective of the step rate test is to determine parting pressure which will establish the upper limit for injection pressure under matrix conditions. 1. S Obtain static pressure survey, install dummy gas lift valves. 2. F MITIA at 2500 psi, step rate injection test. 3. O Place well on water injection (confirm AOGCC approval prior to injection, target and maximum injection rates TBD by step rate test) 4. F AOGCC witnessed MITIA at 2500 psi after injection stabilized. Current Status: Deviation: Last TD Tag: Last Well Op.: Min. Restriction: H2S Info: Shut-in producer 102 deg at 11199 MD 12,368 MD on 12/26/06 12/27/06 CNL borax 3.725" at 5723 MD 15 ppm on 10/28/06 Step Rate Test: 1. RU pump truck with approximately 600 bbls of 130°F 1 %KCI. All fluids should be filtered to 3 microns. (No friction reducer). Trap 1000 psi on the inner annulus. 2. Pump McOH water spear followed by 200 bbls of fitered 2% KCI at maximum rate or a maximum WHP of 3000 psi. Once the rate is established, hold it constant and record the readings every 25 bbls on the WSR. Displacement to the perfs is 172 bbls. 3. Wait 30 minutes. 4. Perform a step rate test at "min rate", 0.5, 0.75, 1, 1.5, 2, 3, 4, 5, and "max rate" BPM if possible with 1 %KCI. Hold the first rate for 10 minutes and the remaining rates for 3 minutes each. Note the rate and pressure at the end of each step on the WSR. (The pressure does not have to be completely stable). 5. Wait 30 minutes and repeat the step rate test. 6. Freeze protect the tubing and RD. • • Contact Dan Robertson at 564-5546 work, 346-3714 home, 529-5818 cell with questions. cc w/a: Well File STATIC BOTTOM-HOLE PRESSURE SURVEY Ver1.4, Rev 08/1?12004 (JDM) Well: W-17a API #: 50-029-21856-01 Date: _ .................................9/22/08.................................... Prod Engr Dan.Robertson......................................................... Office Ph: 564-5546 ............._H2S Levvl_...._.._... Cost Est: $SOM Home Ph: 346-3714 10!28/06,15 m CC or AFE: PBWPDWLI7-R CeIVPager: 529-5818 WBL Entries Type ,Work Description Comments S ?SBHPS, install DGLVs ;Well SI January 2007, ready any time _ _ €_......_ ........................i...................................................._..............._.._....._.._...._..s_........................................................................................................_..._...._.._....._........................................................................ Well Ob'ectives Lo in Notes and S ecial Instructions: Datum: 8800 SS Well Data Procedure: Last lag: -.12368 MD . .. . .. .. . . . . . . . . . . . . . . . Tag date: 12f26/2006 1. Make 10 min pressure stop in lubricator Max Deviation . 102 deb . . . . . . . . . . . . . . . . . . . . . . . . Depth: ,1.11.99. MD 2. Drop below the first pressure-stop requested. Pull-up to specified depth. 3. E/L: Measure pressure until it varies less than 1 psi in 20 min. Min. SI Time: . 2 weeks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Logging Data S/L: Hold guages at depth for time specified 4. E/L: Measure pressure until it varies less than 1 psi in 20 min. S/L: Hold guages at depth for time specified Requested Stops: MD SS Time 5. E/L: Measure pressure until it varies less than 1 psi in 20 min. First 10311' 8700' 20 min S/L: Hold guages at depth for time specified Second .1.0465' _8800' 20 min 6. E/L: Test tool in lubricator at 3000 psi with calibrated test gauge Third na na na S/L: Hold guages in lubricator for 10 min stop. Compare to test guage 7. Leave well shut in it SBHP is less than NA Summa Dist Well: W-17a API #: 50-029-21856-01 PE Town: Date: Anch Prod Engr Service Co. New Tag: 'MD P.D. Center Upper Lower Date Time MD SS Gauge Gauge Temperature Test Gauge Pre-Job Lubricator Pressure ......................................... 10311' 8700' t 0465' 8800' na na 0' 0' Post•JOb Lubricator Pressure ........................................ Type of Pressure Tool SITP (Tubing): psig SICP (9-5/8"): Shut In Date: Comments: and Time: Total Shut In Time TREE= 4-1/16" WELLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 81.62' BF. ELEV = 53.71' KOP = 1484' Max Angle = 102 @ 11199' Datum MD = 11465' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ W-17A G~ CJ Minimum ID = 3.725" @ 5723' 4-1/2" HES XN NIPPLE I CMT PLUG I ¢sv 5599' TBG STUB ~ 7308' 1 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-~ 11417' 7" LNR, 26#, L-80, W4S, ID = 6.276" 11973' ~4-1/2" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" ~ I4-1/2" TIEBACK LNR 12.6#, L-80 I IBT-M, .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: ???? ON ??/??!?? ANGLE AT TOP PERF: 101 @ 11320' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpniSgz DATE 2-7/8" 4 11320 - 11755 O 10!01/05 2-718" 4 11825 - 12080 O 10/01 /05 S TES: 2219' 1--~4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 3560 5590 3223 4782 40 34 KG82 KG82 DOME SO BK BK 16 20 10/27/05 10/27/05 4933' 9-5/8" x 7" BKR ZXP LNR TOP PKR & BKR FLEX LOK LNR HNGR ID = 6.30" TOP OF MILLOUT 9-5/8" WINDOW 5240' 5658' 4-1/2" HES X NIP, ID = 3.813" 5679' 7" X 4-1 /2" BKR S-3 PKR, ID = 3.875" 5702' 4-1/2" HES X NIP, ID = 3.813" 5721' 7" X 5" BKR ZXP LNR TOP PKR &BKR FLEX LOK LNR HNGR, ID = 4.390" 5724' 4-112" HES XN NIP, ID = 3.725" 5736' 4-1/2" WLEG, ID = 3.958" ELMD TT NOT LOGGED 5749' 5" X 4-1/2" XO, ID = 3.96" 10172' 4-1/2" HES ORIFICE FLOAT COLLAR, ID = 3.93" 10181' 4-1/2" X 5" XO, ID = 4.35" 5736' 10184' S" BKR TIEBACK STEM SEAL ASSY w / NO-GO COLLAR, ID = 4.35" 10181' 10179' 7" X 5" BKR ZXP LNR TOP PKR & FLEX LOK LNR HNGR, ID = 4.40" 10207' 5" x a-1/2" x0, ID = 3.95" 7" LNR, 26#, L-80 BTGM, ID = 6.276" (--'1 10330' 4-1/2" LNR, 12.6#, L-80 IBT, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 9/88 ORIGINAL COMPLETION 10/16/90 JQ ORIGINAL COMPLETION 10/03/05 MES SIDETRACK (W-17A) 10/27/05 KSB/TLH GLV GO 12/02/05 MJA/TLH DRLG DRAFT CORRECTIONS ~ 12412' 1 PRUDHOE BAY UNff WELL: W-17A PERMff No: 2051220 API No: 50-029-21856-01 SEC 21, T11N, R12E, 766' FNL & 1183' FEL BP Exploration (Alaska) ~~ +'. ,. i' f M1CR0-FILMED 03/~1/2~Q8 DQ NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE FaLaserFichetCvrPgs_InsertstMicraiilm_Madcer.doc DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2051220 Well Name/No. PRUDHOE BAY UNIT W-17A MD 12500 ND 9051 Completion Date 10/3/2005 Operator BP EXPLORATION (ALASKA) INC Completion Status 1-OIL Current Status 1-OIL API No. 50-029-21856-01-00 c/ UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR /RES / PWD, MWD DIR / GR /RES /AIM, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type. Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 5207 12500 Open 1/13/2005 IIFR pt Directional Surrey 5207 12500 Open 10/13/2005 IIFR Cement Evaluation 5 Blu 1 4932 10179 Case 1/6/2006 Ultrasonic Imaging Tool Cement Evaluation X g Cement Evaluation 5 Blu 1 4932 10377 Case 1/6/2006 ULTRASONIC CEMENT ~ LOG UPDATED ~ ~ USIT/GR/CCL 5'ED C Lis 13415 Casing collar locator 92 10102 Case 1/24/2006 GR ~g Cement Evaluation 5 Col 1 4740 7236 1/24/2006 ULTRASONIC IMAGING TOOL USIT CEMENT EVALUATION '(IS§~ Production 5 Blu 1 10100 12312 Case 2/20/2007 Mem PPL, GR, CCL, TNN, TNF, STP 26-Dec-2006 j C Lis 15230 Induction/Resistivity 5076 12249 Open 6/20/2007 LIS Veri, GR, ROP, Fet w/Graphics PDF and Tif ~g 15230 Induction/Resistivity 25 Blu 5081 12500 Open 6/20/2007 MD Vision Resisistivity 19- Sep-2005 °'Log 15230 Induction/Resistivity 25 Blu 5081 12500 Open 6/20/2007 ND Vision Resisistivity 19- / Sep-2005 ;GAD C Lis 15662 Neutron 10659 12379 Case 11/9/2007 LIS Veri, GR, CNT w/PDS graphics Lo See Notes 2 Blu 10100 12312 Case 11/9/2007 Mem Borax Log. GR, CCL, I' TNN, TNF, STS 26-Dec- 2006 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2051220 Well Name/No. PRUDHOE BAY UNIT W-17A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21856-01-00 MD 12500 TVD 9051 ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? Y'TN,_ Analysis 1`71V" Received? Comments: Compliance Reviewed By: Completion Date 10/3/2005 Completion Status 1-OIL Current Status 1-OIL UIC N Daily History Received? ~ N Formation Tops ~ N Date: ~J 11 /05/07 ~~~F~mW~~~~~ NO. 4360 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & GaS Cons tiOmm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Niakuk, Milne Pt., Pt. Mac, Prince C Wwll .Inh $ Inn rlecr ..~:.... n.,~,, o, n_,_- S-400A 11855508 USIT (REVISED) C 09/18/07 1 C-30 11695080 LDL 10/16/07 1 Z-226 11594525 SBHP SURVEY 10/06/07 1 14-31 11890316 LDL 10/18/07 1 NK-22A 11855822 DRIFT TD/LDL (- 10/25107 1 MPG-07 N/A CORRELATION/DDL ~ 09/08/07 1 • MPG-07 11628799 MEM INJ PROFILE C 10/20/07 1 MPF-10 11767140 MEM INJ PROFILE U= 09/15/07 1 MPS-05 11745237 MEM PPROF SUPPLEMENT LOG - _ 3"7. 10/09/07 1 P2-19A 11649963 MCNL ~ ~ {)(, - 04/22/07 1 1 OWDW-SW 11221548 RST ~, 03/05/06 1 1 W-17A 11588701 MCNL _ ~ tt 12!26106 1 1 14-30A 11485775 MCNL -~ O 11/22/06 1 1 L-51 40013624 OH MWD/LWD EDIT ~ 06/26/06 2 1 r~~e~u~ Mvr~,wrrl-GVVG R~a.ur I of a1VIYIIY~] NIYU RCI URIV IIYV VIYC ~.VI"'T tHl+1'1 1 V: BP Exploration (Alaska) Inc. ~ ~ ~ a~; Petrotechnical Data Center LR2-1 r~ - 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~(*~~~t q~ '-i l~~} Date Delivered: " i`°~ 9 ~ptll`~~!!1!'I Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1 Received by: • ~Y 06/18/07 1-.~F Schlumb~rger N0.4306 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite ao0 ^ _ ~ ~ ~ ^ ~ ~ / `'~~?~ Alaska Oil & Gas Cons 1'omm Anchorage, AK 99503-2838 C-/1`//l Q,/ ( J J Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Woll InF. i! :.... n.. ..u.... L3-12 11695062 PRODUCTION PROFILE 06/06/07 GNI-03 11637128 PRESS/TEMP SURVEY 06/06/07 Y-11C 11661151 MEMORY INJECTION PROFILE 06/01/07 1 C-31B 11745223 MEMORY PROD PROFILE 05/31/07 1 OS-30 11801067 LDL 06/01/07 1 13-29L1 11686753 LDL 05128!07 1 Y-OSA 11628778 MEMORY INJECTION PROFILE 05/28/07 1 L5-23 11661153 MEMORY PROD PROFILE 06/05/07 1 H-37A 11594506 PPROF/IPROF 06/05/07 1 Y-35A 11661152 MEMORY PROD PROFILE 06/03/07 1 N-15 11637129 PRODUCTION PROFILE 06/13/07 1 01-07A 11626098 PRODUCTION PROFILE 05/28/07 1 13-29L1 11686753 LDL 05/28/07 1 04-24 11773112 PRODUCTION LOG 05/19/07 1 12-19 11637343 LDL 06/13!07 1 G-23A 11638639 LDL 06/03/07 1 14-05A 11813055 PPROF W/RST BORAX 06/11107 1 K-12A 11745224 MEMORY PROD PROFILE 06/02/07 1 P2-19A 11661154 MEMORY PROD PROFILE 06/06/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 3-41IK-39 11813054 INJECTION PROFILE 06/08/07 1 3-41IK-39 11813054 INJECTION PROFILE 06/09/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 Z-13A 11649962 MEMORY PROD PROFILE 04l21I07 1 W-17A 40012333 OH EDIT MWD/LWD 09/19/05 2 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: , p , Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: 02/12/2007 5chlumberger NO. 4131 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 / Alaska Oil & Gas Cons Comm Anchorage, AK s95o3-2838 ~~ -/ ~~ Attn: Christine Mahnken aTTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay wnu Inh $ ~ .... nn~...i..a:.... P-27 11588703. MEM GLS 12/29/06 X-26 11536191 INJECTION PROFILE 12/31106 1 W-17A 11588701 MEM PROD PROFILE 12/26106 1 GNI-02A 11540232 INJECTIVITY STEP RATE 01/05/07 1 NK-21 11630446 PROD PROFILE 01/10/07 1 NK-10 11638606 INJECTION PROFILE 01/13/07 1 D-16 11555035 PROD PROFILE 12/26/06 1 LS-25 11538589 LDL 12/28/06 1 Y-16 11626467 LDL 01/19107 1 L-04 11603118 MEM LDL 12/30106 1 ~~.,.,~ .+....,.v..~~.,vc ,.cvc~r: of ow~~~n~a rarvv rccrvrcrvinv vnc ~.uri tH~.n iv: BP Exploration (Alaska) Inc. Petrotechnical Data Center. LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consultor Serv)ces ,-.~ 2525 Gambell Street, Suit '0~~ ~~- ~ ~~~~ ~~_ Anchorage, AK 99503-28`dd --~° '~ 111 ATTN: Beth g a Received by: ~' ~-t » ~i~ ~ p ~i~~ 11 '~~a1~,nn6~~3i1" ~+.m~ i ~s~r;~h.,rS~$0~~d~i~~sBd'l'I a ~~ \.~~, '~~ w STATE OF ALASKA ~ ~yC. ~ ~ ~ cu~~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERlO'I~~~ ~~~l~. ~f~~lTl~~si~ 1. Operations Performed: Abandon^ Repair Well^ Plug Perforations^ Stimulate Q Other^ Alter Casing^ Pull Tubing^ Perforate New Pool^ Waiver^ Time Extension^ Change Approved Program^ Operation Shutdown^ Perforate ^ Re-enter Suspended Well^ 2. Operator BP Exploration (Alaska), Inc. Name: 4. Current Well Class: Development ^X Exploratory^ 5. Permit to Drill Number: 1 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-8612 Stratigraphic^ Service^ 50-029-21856-01-00 7. KB Elevation (ft): 9. Well Name and Number: 84.58 W-17A 8. Property Designation: 10. Field/Pool(s): ADL-047451 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 12500 feet true vertical 9051.0 feet Plugs (measured) Effective Depth measured 12411 feet Junk (measured) true vertical 9036.0 feet None None Casing Length $izg MD TVD Burst Collapse CONDUCTOR 110 20" 91.5# H-40 31 - 141 31.0 - 141.0 1490 470 SURFACE 2824 13-318" 68# L-80 30 - 2854 30.0 - 2686.0 4930 2270 PRODUCTION 5211 9-5/8" 47# L-80 29 - 5240 29.0 - 4506.0 6870 4760 LINER 5397 7" 26# L-80 4933 - 10330 4280.0 - 8796.0 7240 5410 LINER 6777 4-1/2" 12.6# L-80 5721 - 12498 4894.0 - 9051.0 8430 7500 Perforation depth: Measured depth: 11320-11755, 11825-12080 True vertical depth: 9019-8941, 8940-8980 Tubing (size, grade, and measured depth): 4.112" 12.6# L-80 @ 28 - 5738 Packers & SSSV (type & measured depth): 9-5/8" BKR ZXP LNR Top PKR @ 4933 7" Baker S-3 Packer @ 5679 7" BKR 2.XP LNR Top PKR @ 5721 7" BKR ZXP LNR Top PKR @ 10179 4-112" HES X Nipple @ 2219 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure; ~ ~ <- ~- ~ ~ s ~ ~ ,~~~~ 13 Representative Daily Average Production or Infection Data Prior to well operation, Subsequent to operation Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 57 543 202 --- 264 58 537 187 --- 225 5. Well Class after proposed work: Exploratory^ Development^X Service^ Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ X Oil^X Gas^ WAG ^ GINJ^ WINJ^ WDSPL^ Prepared by DeWayne R. Schnorr (907) 564-5174 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 DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature Phone 564-5174 Date 10/24/06 Form 10-404 Revised 4/2004 • W-17A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY AWGRS 04/23/2006 ****WELL SHUT IN ON ARRIVAL**** (drift to dev. pre acid stim) DRIFT WITH 3.50 CENT & S.B. TO 10672' SLM STOP DUE TO DEV. ****LEFT WELL SHUT IN**** AWGRS 05/07/2006 T/I/0=2040/1970/100. Temp=Sl. TIFL PASSED (pre-Drift, pre-Acid). IA FL @ 5590' (275 bbls) (SO). Bled IAP from 1940 psi to 690 psi in 1 hour, 30 minutes. Post bleed IA FL remained the same. TP decreased from 2040 psi to 2030 psi, OAP decreased from 100 psi to 80 psi during IAP bleed. Monitor 1 hour. Post monitor IA FL remained the same. **Note** Blocked A/L line in @ lateral valve & bled A/L dogleg simultaneous w/IAP. Blocked in @ A/L casing valve post IAP bleed. A/L companion was hydrated off on arrival. FO w/call for flowline FP. Final T/I/0=1950/700/80. AWGRS 05/08/2006 T/I/0=1810/885/90. Temp=S1. WHP's post-TIFL (pre-drift, pre-acid). TP decreased 140 psi, IAP increased 185 psi, OAP increased 10 psi overnight. **Note** A/L P=920 psi. A/L casing valve still blocked in w/heavy frost noted on A/L lateral, dogleg & companion. FO blocked in A/L @ skid & bled line to 240 psi. Skid valve wouldn't hold. Called grease crew to grease all valves & bleed A/L to 0 psi. AWGRS 05/09/2006 T/1/0= 154011080190. Temp= SI. WHP's post-TIFL (pre-drift, pre-acid). Tubing pressure decreased 270 psi. IAP increased 195 psi. A/L line pressure @ 1850 psi. Lateral & A/L line SI. Valve crew greased valves monday afternoon. AWGRS 05/13/2006 T/I/0=1400/1150/50. Temp=S1. Check for AL line blind (pre-TIFL). TBGP decreased 140 psi, IAP increased 70 psi, & OAP decreased 40 psi since 5-8-06. AL line has 2" slip blind at the casing valve. AWGRS 05/14/2006 T/I/0=1410/1070/110. Temp=Sl. TIFL PASSED. (Pre-Acid Stim). IA FL @ 5590' sta#1 S/O (276 bbl). Bled IAP (to swab on well W-16) from 1070 psi to 280 psi in 2 hours. No change in IA FL during bleed. TP decreased 40 psi during the 1st hour of the bleed, no change in TP after 1st hour. OAP decreased 10 psi during the 1st hour of the bleed, no change in OAP after 1st hour. Monitor for 1 hour. TP increased 20 psi during monitor. No change in IAP or IA FL during monitor. No change in OAP during monitor. Final WHP's=1390/280/100 AWGRS 05/15/2006 T/I/O = 1390/280/100. Temp = SI. WHPs post TIFL (pre-acid stim). No change in pressures overnight. TestEvent 07/04/2006 BOPD: 62 BWPD: 192 MCFPD: 3,528 AL Rate: 3,030 AWGRS 10/13/2006 ASRC Well Testing -Unit #2 standing by for GC-2 to come back online. AWGRS 10/20/2006 CTU #6, Acid Stimulation; Wait for VECO to rig up hardline. MIRU unit. Conduct weekly BOP test. MU and RIH with 3.5" JSN for drift. Attempt to kill well and WHP quickly came up to 2500 psi. Bleed WHP and RIH. Tag ice at 1667' ctmd. Jet hard ice plug down to 1960' ctmd.... Job in Progress ... AWGRS 10/20/2006 CTU 6 -Acid Wash Perfs -MIRU -Conduct weekly BOPE test - Page 1 • • W-17A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS AWGRS 10/21/2006 CTU #6, Acid Stimulation; Tag obstruction at 10728' ctmd. Unable to jet obstruction with nozzle after several minutes. POOH. MU and RIH with WFD 2-7/8" motor and 3.6" OD 5-blade junk mill. Tag obstruction at 10725'. Mill through obstruction with very little motor work. Continue in hole no motor work. Tag bottom at 12417' ctmd. POOH; tools pulling junk up hole seeing large overpulls. Lost junk in liner tie back sleeve at 10200'. POOH. MU and RIH with SLB Jetblaster with 2.7" OD drift ring.... Job in Progress ... AWGRS 10/22/2006 CTU #6, Acid Stim; RIH with Jet Blaster and jet perfs with 246 bbls 15% 90:10 DAD, 246 bbls 9:1 Mud Acid and 660 bbls 3% NH4CL AWGRS 10/22/2006 CTU #6, Acid Stimulation; Cont' RIH with SLB Jet Blaster. Tag XO at 10204' ctmd; Surge pumps reciprocate coil and made it past. Pump 80 bbls NH4CL (150 bbls NH4CL in well borefollowed by 100 bbls of diesel. Infectivity 0.8 bbls at 2200 psi with diesel in hole (max pressure/rate to stay under frac gradient). RU dowel) acid pumpers and begin pumping 90:10 DAD acid. With 32 bbls of acid in the coil and 2 bbls from acid at the nozzle, o-ring in lubricator failed. Set pipe and slip rams, bleed WHP to 0 psi, freeze protect coil with 60/40. Fixed and pressure tested new o-ring. Resumed pumping 90:10 DAD acid. Note that injectivity increased to 1.0 bpm at 1000 psi with the 32 bbls of acid that had to be flushed from coil when o-ring failed. Pumped acid stages as per procedure. Stimulated interval 11825-12080 with 56 bbls of 90:10 DAD acid, 91 bbls of 9:1 mud acid and 177 bbls of 3% NH4CL overflush. Stimulated interval 11320-11755 with 155 bbls of 90:10 DAD acid, 155 bbls of 9:1 mud acid and 302 bbls of 3°!° NH4CL overflush.... Job in Progress ... AWGRS 10/23/2006 CTU #6, Acid Stimulation; POOH pumping 60/40 meth down backside to replace coil voidage, 34 bbls total. Final injectivity 1.1 bpm at 1100 psi. RDMO. "** Job Complete *** AWGRS 10/24/2006 ASRC Well Test (Post acid flowback ) FLUIDS PUMPED BBLS 185 60/40 Methanol Water 300 1 %KCL Water 250 1 % Extra Slick KCL Water 145 Diesel 660 3% NH4CL 246 90:10 DAD Acid 246 9:1 Mud Acid 100 Soda Ash 10 Flo Pro 2142 TOTAL Page 2 Schiumherger Alaska Data 8, Consulting Services 2525 Garnbell Street, Suite 400 Anclioraye, AK 99503-2838 ATTN: Beth wan r„-. ~ ~V~~ V ~~ tJA~s 2 4 2006 ~'~ $c GaS Cvf1S. ~'~ Ait(~1Ci3CJ2 NO. 3668 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. 01 /23/06 D-1U 10913021 LDL 06/02/05 1~ vu Z-24 11183454 LDL 12/29/05 1 DS 13-22 10987560 INJECTION PROFILE 01/05/06 1 G-11A (REDO) 11084277 RST-SIGMA 07/12/05 1 W-17A Qrj - ~ p~ 10987549 USIT-PDCL 09/20!05 1 02-176 10928646 MCNL 09/13/05 1 1 MPS-10A 11076475 SCMT 10!17/05 1 W-17A QS~1 eta 10913044 USIT 09/03/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambetl Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ _ Received by C • 12/21/05 ~lU~luili~ril-g~s~ N0.3628 Alaska Data & Consulting Services ~C~ ~ ~, /Ct~i pany: State of Alaska 2525 Gambell Street, Suite 400 C V C ~J Alaska Oil 8: Gas Cons Comm Anchorage, AK 99503-2838 Attn: Helen Warman ATTN: Beth 333 West 7th Ave, Suite 100 JAN p 6 2006 Anchorage, AK 99501 ~1+85~(3 Q~~ 8c Ga$ COnS. COIntT~S~n Prudhoe Bay, Milne Pt. Anchorage Well Job # Lo Descri lion Date BL Color CD W-17A 10987549 USIT 09121/05 1 W-17A 11058537 USIT 09/24/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth n^ Received bl(: • STATE OF ALASKA NOV ~ ~ 205 ALASKA OIL AND GAS CONSERVATION COMSION WELL COMPLETION OR RECOMPLETION REPORT AND LO~a~ka pal ,~ Gaa Cons. CommiSSIOD Anchorage 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other Pre-Produced Injector ib. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 10/3/2005 12. Permit to Drill Number 205-122 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 9/10/2005 13. API Number 50- 029-21856-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 9/19/2005 14. Well Name and Number: PBU W-17A 766 FNL, 1183 FEL, SEC. 21, T11 N, R12E, UM Top of Productive Horizon: 815' FNL, 3740' FWL, SEC. 22, T11N, R1.2E, UM g, KB Elevation (ft): 84.56' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 1368' FNL, 271' FWL, SEC. 23, T11N, R12E, UM 9. Plug Back Depth (MD+TVD) 12411 + 9036 Ft 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 612049 y- 5959491 Zone- ASP4 10. Total Depth (MD+TVD) 12500 + 9051 Ft 16. Property Designation: ADL 047451 TPI: x- 616971 y- 5959517 Zone- ASP4 Total Depth: x- 618792 Y- 5958992 Zone- ASP4 11 • Depth where SSSV set None MD 17. Land Use Permit: ----~~~---~---" ~ ~ ---------- 18. Directional Surrey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.] 21. Logs Run: MWD DIR / GR /RES / PWD, MWD DIR / GR /RES /AIM, USIT 2. ASING, LINER AND CEMENTING RECORD CASING INO EPTH MD ETTINO EPTH TVD HOLE MOUNT SIZE WT. PER FT. GRADE OP " TTOM OP TTOM SIZE CEMENTING RECORD PULLED 20" Conductor Surface 110' Surface 110' cu ds Concrete 13-3/8" 68# L-80 Surface 2854' Surface 2686' 17-1/2" 128 cu ft Permafrost 9-5/8" 47# L-80 Surtace 5240' Surtace 4506' 12-1/4" 465 cu ft Class 'G' 7" 26# L-80 4933' 10328' 4280' 8796' 8-1 /2" 31 cu ft LiteCrete, 197 cu ft Class 'G' 4-1/2" 12.6# L-80 5721' 12498' 4894' 9051' 6-1/8" 37 cu ft Class'G', 483 cu ft Class'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2.88" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 5736' 5679' MD TVD MD TVD 11320' - 11755' 9019' - 8941' 11825' - 12080' 8940' - 8980' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Si KIND OF MATERIAL USED 5829' - 5844' Remedial Cement Squeeze Perts: 15 Bbls Class 'G' 5884' - 5899' " Freeze Protect with 155 Bbls of Diesel 26. PRODUCTION TEST Date First Production: November 7, 2005 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 11/9/2005 Hours Tested 6 PRODUCTION FOR TEST PERIOD OIL-BBL 105 GAS-MCF 48 WATER-BBL 84 CHOKE SIZE 176 GAS-OIL RATIO 457 Flow Tubing Press. 30 Casing Pressure 1150 CALCULATED 24-HOUR RATE OIL-BBL 420 GAS-MCF 192 WATER-BBL 336 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ' ~ None ti ~' ~ gpy~r~ ~~yq pp~~ q~ (j(~ i~F-6Z t ..=1 -~. Form 10-407 Revised 12/2003 ! DTI JUED ON REVERSE $IDE _~ ~ ~1r '~ 4 ~.~*~ k t 28. GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu MA 5381' 4615' None Schrader Bluff OA 5846` 5005' Schrader Bluff OBa 5904' 5059' Schrader Bluff OBb 5934' 5087' Schrader Bluff OBc 5983' 5133' Schrader Bluff OBd 6043' 5189' Schrader Bluff OBe 6115' 5256' Schrader Bluff OBf 6160' 5298' Base Schrader Bluff /Top Colville 6211' 5346' H RZ 7632' 6686' Kalubik 7888' 6926' Miluveach 7891' 6928' Kingak 8520' 7469' Sag River 10332' 8799' Shublik 10370' 8825' Eileen 10530' 8919' Sadlerochit 10555' 8932' Sadlerochit 11796' 8939' Sadlerochit 11802' 8939' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ) ~ /~b! Signed Terris Hubble Title Technical Assistant Date ~ / ubble, 564-4628 PBU W-17A 205-122 Prepared By Name/Number.~ Terris H Well Number Permit No. / A royal No. Drilling Engineer: Dave Wesley, 564-5153 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. - ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). 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 Printed: 10/10/2005 11:35:15 AM • BP Exploration Operations Summary Report Page 1 of 17 Legal Well Name: W-17 Common Well Name: W-17 Spud Date: 8/20/1988 Event Name: REENTER+COMPLETE Start: 8/20/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date From - To I Hours II Task ~ Code NPT Phase L - _ - 8/22/2005 08:00 - 10:30 2.50 MOB P PRE 10:30 - 11:00 0.50 MOB P PRE 11:00 - 12:00 1.00 MOB P PRE 12:00 - 12:30 0.50 MOB P PRE 12:30 - 14:00 1.50 MOB P PRE 14:00 - 15:00 1.00 MOB P PRE 15:00 - 00:00 9.00 MOB N WAIT PRE Description of Operations - R.D floor equip't & R/U to UD derrick. - PJSM & UD derrick. - Disconnect service lines from pits. - Prep & pull pit complex away from substructure. - Prep substructure to move off of well. - Move substructure away from well row & park on S-Pad. - Perform the following tasks while awaiting coil tubing unit to complete preparation work on W-17: - Welded leak on hot well tank. - C/O steam line valves. - Clean derrick & wind walls. - Remove agitator motor from pits. - Perform the following while awaiting coil tubing unit to complete preparation work on W-17: - Fill repaired hot well tank & bring steam system back on line. - Install 2 agitiator motors in pits. - Load trucks destined for W-Pad. - Replace & insulate leaking steam valves. - Repair winch line on man rider. - Clean rig. - Continue waiting for preparation work on W-17 to be completed. - Clean wind walls & derrick. - Place mats on S-pad. - Service drawworks & top drive. - Paint stairs & hand rails. - Cut out pit room wall for shaker removal. - Move pit complex away from well row for slick line access to S-118. -Cleaning rig on S-Pad. - Modify drillers console guard. - Service & paint air slip controls. - Remove, rebuild, & reinstall Burgess degasser. - Clean, paint, & perform routine maintenance on rig while standing by Q S-Pad awaiting completion of W-17 prep work. 8/23/2005 100:00 - 00:00 I 24.001 MOB I N 8/24/2005 100:00 - 00:00 I 24.00 I MOB I N 8/25/2005 100:00 - 00:00 I 24.001 MOB I N 8/26/2005 00:00 - 00:00 24.001 MOB N 8/27/2005 ~ 00:00 - 00:00 ( 24.001 MOB N 8/28/2005 ~ 00:00 - 19:00 ~ 19.00 MOB ~ N 19:00 - 00:00 5.00 ~ MOB P 8/29/2005 100:00 - 07:30 I 7.501 MOB I P WAIT I PRE WAIT I PRE WAIT I PRE WAIT I PRE WAIT PRE -Clean, paint, & perform routine maintenance on rig while standing by C~ S-Pad awaiting completion of W-17 prep work. - Adjust top drive service loop hydraulic hose. WAIT PRE -Clean, paint, & perform routine maintenance on rig while standing by C~ S-Pad awaiting completion of W-17 prep work. - W-17 well work update: E-line cut 3 1/2" tubing w/jet cutter ~ 7320'. R/D E-line & coil unit. Remove well houses & flow line. Haul gravel & level pad while moving operations in progress from S-Pads to W-pad. PRE -Back up trucks underneath pit complex & camp, load shop, and move to W-Pad. PRE -Spot shop & camp on W-Pad & park pits out of way until substructure arrives. - Lay additional mats on S-Pad along road by manifold building due to soft spots close to road shoulder. Printed: 10/10/2005 11:35:22 AM • BP Exploration Operations Summary Report Page 2 of i 7 Legal Well Name: W-17 Common Well Name: W-17 Spud Date: 8/20/1988 Event Name: REENTER+COMPLETE Start: 8/20/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Hours I' Tas~Code ` NPT I Phas ~ Description of Operations Date ~ From - To - - - ' - -- 8/29/2005 ~ 00:00 - 07:30 ~ 7.50 I MOB ~ P 07:30 - 13:00 I 5.501 MOB I P 13:00 - 16:00 I 3.001 MOB I P 16:00 - 00:00 I 8.00 I MOB I P 8/30/2005 00:00 - 03:00 3.00 MOB P 03:00 - 00:00 21.00 MOB P 00:00 - 18:00 I 18.001 MOB I P 18:00 - 22:00 I 4.00 I MOB I P 22:00 - 00:00 I 2.001 BOPSUR P 9/1/2005 ~ 00:00 - 00:30 0.50 ~ WHSUR P 00:30 - 02:00 1.50 PULL P 02:00 - 06:30 4.50 KILL P 06:30 - 07:30 I 1.001 WHSUR I P 07:30 - 11:00 I 3.501 WHSUR P 11:00 - 12:00 I 1.001 WHSUR I P 12:00-13:30 ~ 1.50~WHSUR~P 13:30 - 15:30 I 2.001 WHSUR I P PRE -Move Substructure to S Pad access road Y. -Hydraulic pressure on moving system jacks as follows: Pit complex -left rear - 300 psi, right rear - 900 psi. Rig camp -left rear - 1200 psi, right rear - 1200 psi, left front - 1000 psi, right front - 1000 psi Rig sub -left rear - 1430 psi, right rear - 1630 psi, left front - 940 psi, right front - 987 psi. PRE -Stage rig at S Pad access road Y. Pick up all mats behind rig & haul to W Pad ahead of rig for contingency. PRE -Move substructure from S-Pad access road Y to W Pad access road. PRE -Blew out road with rig 1.3 miles from W-Pad along W-Pad access road. Jack rig, stuff matting boards & lumber in holes & attempt to move rig forward without success. - Decision made to mat the entire road for the remaining 1.3 miles onto pad. Lay mats while trying to free rig . PRE Continue jacking up rig & place lumber underneath rear tires in attempts to make forward progress. PRE Rig free of holes in road. Move rig to the end of the matted section of road. Lay double mats behind rig. Place approximately 60 along the road behind the rig. Back rig up over doubled mats and move mats to single layer in front of rig. Repeat process moving rig and mats toward location. PRE Continue placing double matting to move rig onto location. At 06:00 1/4 mile from location. PRE Spot rig over W-17A. PJSM. Inspect derrick. Raise derrick. RU chute. Bridle down. Spot pits. Spot MI, MWD, geologist trailer. Take on heated seawater. DECOMP Accept rig at 22:00. RU lines and hoses to well head. Prepare to reverse circulate diesel freeeze protection from wellbore w/140 deg. F. 8.4 ppg seawater. RU DSM lubricator to pull BPV. DECOMP Prespud meeting with crew and service company personel / PJSM. DECOMP RU and test lines to 3500 psi. Pull BPV with DSM lubricator. DECOMP Reverse circulate 20 bbls. of 8.5 ppg. seawater to displace diesel from tubing at 5 bbls/min. Change over and circulate conventionally. Pump 50 bbls. of soap sweep in front of 550 bbls. hot 8.5 ppg. seawater at 3 bbls/min Ca3 130 psi. Take returns through choke to cuttings tank. Gas and crude oil returns. DECOMP RU equipment to run TWC. Monitor well. Well started making gas. DECOMP Circulate 140 degree 8.5 ppg seawater, stop circulating periodically to allow gas and oil to migrate up. Circulating 4 bpm @ 130 psi. DECOMP RU DSM lubricator and Install Two way check valve in tubing hanger. Prespud meeting with crew and service company personel /PJSM. DECOMP Test TWC to 1000 psi from below. RD DSM. RD circulating lines and hoses. DECOMP Nipple down tree. Inspect tubing hanger lifting threads, found to be 8rd 3 1/2", confirm with cross over. Printed: 10/10/2005 11:35:22 AM BP Exploration Page 3 of 17 Operations Summary Report Legal Well Name: W-17 Common Well Name: W-17 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 7ES Start: 8/20/2005 Rig Release: Rig Number: Spud Date: 8/20/1988 End: Date "From - To I Hours I'~ Task ~ Code ~ NPT ~' Phase I Description of Operations 9/1/2005 15:30 - 17:30 2.00 BOPSU P DECOMP Nipple up BOP. 17:30 - 18:30 1.00 BOPSU P DECOMP MU/RU BOP test equipment. 18:30 - 21:30 3.00 BOPSU P DECOMP Test BOPs, AOGCC rep Chuck Scheve waived his witnessing of BOP test, 250 psi low pressure test 2500 psi high pressure test on annular, 250psi low pressure test 4000 psi high pressure test on all other tests including BOPE, choke manifold, TD, and floor valves. Test witnessed by Ray Barnes Nabors tourpusher and Lowell Anderson BP WSL. 21:30 - 22:00 0.50 BOPSU P DECOMP RD and LD all test equipment, blow down lines. 22:00 - 23:30 1.50 PULL P DECOMP RU to pull 3.5" tubing hanger. RU Camco control line spooling ! unit. 23:30 - 00:00 0.50 PULL P DECOMP RU DSM lubricator to pull TWC. 9/2/2005 00:00 - 01:00 1.00 BOPSU P DECOMP Pull TWC with DSM lubricator. 01:00 - 02:00 1.00 BOPSU P DECOMP RU to pull hanger and tubing. Screw into hanger with 3 1/2" 8rd ~ cross over and 4" drill pipe. Back out lock down screws. PU 85K Ibs including top drive and pull hanger and tubing free. No trouble pulling, no overpull. Control lines attached at surface and in good shape. 02:00 - 03:00 1.00 BOPSU P DECOMP RU and circulate 1 bottoms up, 480 bbls seawater. 305 gpm @ 885 psi. 03:00 - 12:30 9.50 PULL P DECOMP LD hanger. Pull and lay down 226 joints 3-1/2" 9.2 Ib. EUE 8rd tubing and completion equipment. Cut off 3 1/2" stub at 7308'. Cut was clean. Spool up control lines. Mark tbg. w/jt. number and well number. Recovered 32 clamps and 4 SS bands. 12:30 - 13:30 1.00 PULL P DECOMP Rig down tubing handling equipment. 13:30 - 16:00 2.50 BOPSU P DECOMP RU & test lower pipe rams low 250 psi, high 4000 psi to complete BOP test. Install wear bushing. RD test equipment. Blow down lines. 16:00 - 19:00 3.00 CLEAN P DECOMP PJSM. PU #1 BHA 8.5" OD mill, 9 drill collars, jars, 24 HWDP. 19:00 - 00:00 5.00 CLEAN P DECOMP RIH with 4" drill pipe, picking up singles and tag stub @ 7308'. No problems getting to bottom. Up wt. 150K, do wt. 120K, rot. wt. off 137K, tq. off 2900. 9/3/2005 00:00 - 01:00 1.00 CLEAN P DECOMP Circulate well to clean seawater w/537 bbls @ 450 gpm, 1595 psi. 01:00 - 05:00 4.00 CLEAN P DECOMP POH w/BHA #1 flat bottom mill cleanout assy. Standing back collars and HWDP. 05:00 - 06:00 1.00 STMILL P WEXIT PJSM w/all hands and WSL. RU Schlumberger wireline for USIT log. 06:00 - 10:00 4.00 STMILL P WEXIT Run Schlumberger USIT bond log from 7308' to 4700', checking cement behind 9-5/8" casing. Cement quality poor and channeled. 10:00 - 10:45 0.75 STMILL P WEXIT 9-5/8" casing pressure test to 4000 psi. Hold f/30 min. 10:45 - 12:00 1.25 STMILL P WEXIT Run and set EZSV bridge plug @ 5585' on wireline using collar locator to correlate. 12:00 - 13:00 1.00 STMILL P WEXIT POH w/wireline and RD wireline unit. 13:00 - 13:45 0.75 STMILL N RREP WEXIT Replace electrical solenoid, failure of which had locked draw works disc brake. 13:45 - 15:30 1.75 STMILL P WEXIT PU section mill (BHA #2). Consisting of: section milling tool, bit sub, x-over sub, 9 drill collars, x-over sub, jars and 24 jts of HWDP. 15:30 - 18:00 2.50 STMILL P WEXIT RIH to 5599' and tag up on EZSV. Correlate casing collars to w/I measurements. PU to 5594' and spot 18.0 ppg pill f/5599' Printed: 10/10/2005 11:35:22 AM • BP Exploration Page 4 of ~ 7 Operations Summary Report Legal Well Name: W-17 Common Well Name: W-17 Spud Date: 8/20/1988 Event Name: REENTER+COMPLETE Start: 8/20/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code j NPT ~ Phase Description of Operations 9/3/2005 15:30 - 18:00 2.50 STMILL P WEXIT to 5399' w/9.0 ppg LSND milling fluid. 18:00 - 19:30 1.50 STMILL P WEXIT Displace well to 9.0 ppg LSND milling fluid. Spot 16 bbls of 18.0 ppg pill 19:30 - 20:00 0.50 STMILL P WEXIT POH to 5240', record SPRs. 20:00 - 22:30 2.50 STMILL P WEXIT Attempt to section mill (/5240'. Up wt. 130K, SO 110K, rot wt. 120K, 208 gpm, 712 psi. Lost 35 bbls mud over shakers. ~ Slowed pump rate and changed screens f/84 to 38s w/no long term improvement. Found paraffin was plugging screens. Treated for paraffin w/EMI 697 until system stabilized. 22:30 - 00:00 1.50 STMILL P WEXIT Section milling f/5240' to 5243'. Up wt. 130K, SO wt. 110K, rot wt. 120K, 85 rpm, tq. on 2100, 400 gpm @ 1325 psi. 9/4/2005 00:00 - 12:00 12.00 STMILL P WEXIT Section milling 9-5/8" casing f/5243' to 5263'. Up wt. 130K, SO wt. 110K, rot wt. 120K, 100 rpm, tq. on = 6K ft. lbs., tq. off 4K ft. lbs., 450 gpm @ 1550 psi. 12 hrs. = 624 # casing shavings recovered from shakers. Pumped 35 bbl. hi-vis super sweep 5263'. Slight increase in cuttings seen. 12:00 - 00:00 12.00 STMILL P WEXIT Section milling 9-5/8" casing f/5263' to 5289'. Up wt. 130K, SO wt. 110K, rot wt. 120K, 100 rpm, tq. on = 6K ft. lbs., tq. off 4K ft. lbs., 500 gpm @ 1800 psi. 12 hrs. = 924 # casing shavings recovered from shakers. Pumped 30 bbl. to-vis sweep followed by 79 YP mud ~ 5287'. 50 Ib. slug of cuttings came across shakers. 24 hr. casing shavings total = 1548 lbs. 46' milled = 2162 Ibs.milled = 72 % recovery. 24 hr. milling rate = 1.92'/hr. 9/5/2005 00:00 - 12:00 12.00 STMILL P WEXIT Section milling 9-5/8" casing f/5289' to 5320'. Up wt. 130K, SO wt. 110K, rot wt. 120K, 100 rpm, tq. on = 7.5K ft. lbs., tq. off 4K ft. lbs., 500 gpm @ 1850 psi. 1365 lbs. casing shavings recovered from shakers in 12 hrs. 12:00 - 00:00 12.00 STMILL P WEXIT Section milling f/5320' to 5342'. Up wt. 130K, SO wt. 110K, rot wt. 120K, 100 rpm, tq. on = 7K ft. lbs., tq. off 5.5K ft. lbs., 525 gpm @ 2085 psi. 1512 lbs. casing shavings recovered from shakers in 12 hrs. Pumped HiVis, HiVis/weighted and LoVis sweeps w/no increased cuttings retrieval. 24 hr. casing shavings total = 2877 lbs. 53' milled = 24911bs. 24 hr. milling rate = 2.21 ft./hr. Since startup 102' of casing milled = 4794 lbs. milled. Since startup 4425 lbs. of casing shavings recovered = 92% of casing shavings recovered at surface. 9/6/2005 00:00 - 08:30 8.50 STMILL P WEXIT Section milling 5342' to 5365'. Up wt. 130K, SO wt. 110K, rot wt. 120K, 100 rpm, tq. on = 7.5K ft. lbs., tq. off 5.5K ft. lbs., 525 gpm C~ 2120 psi. 08:30 - 09:30 1.00 STMILL P WEXIT Pump 40 bbl. to-vis (90 vis) sweep. Casing shavings total recovery for 125' section milling job = 5477 lbs. of 5875 lbs. total available for recovery. 398 lbs. lost to well bore. 93% recovery of cuttings. 09:30 - 10:15 0.75 STMILL P WEXIT Back ream to shoe, work to circulate out bird's nest. RIH to bottom. Printed: 10/10/2005 11:35:22 AM • BP Exploration Operations Summary Report Page 5 of 17 Legal Well Name: W-17 Common Well Name: W-17 Spud Date: 8/20/1988 Event Name: REENTER+COMPLETE Start: 8/20/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date 9/6/2005 From - To Hours Task Code' NPT Phase 10:15 - 11:00 0.75 STMILL P 11:00 - 12:00 1.00 STMILL P 12:00 - 15:30 3.50 STMILL P 15:30 - 16:30 1.00 STMILL P 16:30 - 17:00 0.50 STMILL P 17:00 - 21:00 4.00 STMILL P 21:00 - 00:00 3.00 STMILL P 9/7/2005 00:00 - 01:00 1.00 STMILL N 01:00 - 03:00 2.00 STMILL N 03:00 - 04:30 1.50 STMILL N 04:30 - 05:00 0.50 STMILL N 05:00 - 07:30 2.50 STMILL N 07:30 - 10:30 3.00 STMILL N 10:30 - 11:30 1.00 STMILL N 11:30 - 12:00 0.50 STMILL N 12:00 - 13:00 1.00 STMILL N 13:00 - 16:00 I 3.001 STMILL I N 9/8/2005 16:00 - 17:00 17:00 - 18:00 18:00 - 20:00 20:00 - 22:00 22:00 - 22:30 22:30 - 23:00 23:00 - 00:00 00:00 - 02:00 1.00 STMILL P 1.00 STMILL N 2.00 STMILL N 2.00 STMILL N 0.50 STMILL N 0.50 STMILL N 1.00 STMILL N 2.00 STMILL N 02:00 - 04:30 I 2.501 STMILL I N 04:30 - 05:00 I 0.501 STMILL I N WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB IWEXIT WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB IWEXIT DPRB IWEXIT Description of Operations Circulate bottoms up. 500 gpm, 100 rpm, 2100 psi. POH. Experience excessive swabbing. Pump out to 2443', stuck pipe. PU bumper sub and work stuck pipe free. Circulate. Packing off. Losing mud to formation while pumping 450 gpm @ 1925 psi. Pump out of hole to 300'. Pulled to jars and packed off, 20K overpull, regained circulation, worked down 15' and packed off. Pipe stuck. PJSM. All non essential personnel off rig floor. Pulled 350K up. Trip jars. SO all available. Moved pipe up 1'. Jars tripped 7-8 times and failed. Order out surface jars. Mobilize surface jars. Rig up and adjust trip point on surface jars. Jar stuck pipe w/surface jars @ 300'. Pull 150K up and trip jars. Work jars 30-40 hits. Perform top drive and derrick inspection after jarring. Call and consult w/town engineer. Order out Schlumberger wireline unit to run string shot at crossover sub between drill collar # land drill collar #2. Mobilize Schlumberger wire line unit. Spot and RU wireline unit. RIH w/string shot to xover between #1 and # 2 drill collar. Backoff. RD wireline and clear floor. LD backed of pipe consisting of : 1 jt. HWDP, XOs, & Oil Jar. No collars retrieved. Backed off of top drill collar. Repair IBOP damaged while jarring on stuck pipe w/surface jars. Change saver sub guide block, & grabber to 4-1/2" IF. Inspect derrick. Perform maintenance on top drive. Cut and slip drilling line. PU jetting tool and jet BOP stack. Recover 405 Ibs of metal and debris. LD jetting tool. PU wash over assembly consisting of burn shoe, 3 jts of washpipe, drive sub, jars. Wash over drill collars f/33' to 113'. 550 gpm, 100 psi, 50 rpm, tq 2K to 37'. No tq. to 113'. Recover 58 Ibs. shavings. PU 1 jt. HWDP &RIH to check if fish still in place. Fish fell away. Stand back 3 jts. wash pipe. RD bails, change saver sub, guide block, & grabber to HT 40". PU fishing BHA consisting of screw in sub, circulating sub, 2 bumper subs, jars, x-over, 3 drill collars, x-over, accelerators, x-over to HT-40". RIH to fish. Tag up at 510'. Pump 1 bbl/min C~3 1000 psi. Try to screw in. No wt. indication that fish was engaged. Saw 1 K fUlbs torque. Make 2 attempts. Pump 1 bbl/Imin @ 1000 psi. Saw 1 K ft./Ibs torque. Pull 2 stands. No weight indication. Pump 1 bbl/min C~ 1000 psi. POH f/320'. No fish. 11b. magnetized metal gathered in bumper sub mandrel. Suspect pressure indications came from pumping metal shavings above screw in sub in annulus. RIH w/ screw in sub BHA staging in hole utilizing pumps. Roll Printed: 10/10/2005 11:35:22 AM BP Exploration Operations Summary Report Page 6 of 17 Legal Well Name: W-17 Common Well Name: W-17 Spud Date: 8/20/1988 Event Name: REENTER+COMPLETE Start: 8/20/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date 'I From - To 'Hours Task II Code' NPT Phase I -- 9l812005 `04:30 - 05:00 I 0.50 STMILL 1 N DPRB WEXIT Description of Operations pumps, 3500 psi, hydraulic BHA out of hole. POH f/130'. Srcew in sub packed solid with metal shavings. Clean out same RIH w/screw in sub BHA + magnet sub staging in hole utilizing pumps. MU BHA wl magnet and screw in sub. RIH in hole. Circ. down each std. C~ 500 gpm. Engage fish @ 1215'. Set 20K down. Screw in fish w/8K torque. POH pumping at maximum pumping rate. POH. LD Drill collars, fishing tools, and fish 9 DC. Section mill in good shape. LD fishing jar assy. and wash pipe 3jts + burn shoe. PU jetting tool and jet stack clean. 127 # iron recovered. LD jetting tool. Pull wear bushing, inspect, reinstall. PU 3-1/2" tubing/cement stinger consisting of 20 jts. 3-1/2" tubing, perforated plug catcher, and appropriate x-overs. BHA length = 649.99'. PJSM &RIH w/20 jts. tubing. RD tubing running equipment. RIH w/cement stinger on DP, CBU every 1000' to 4954', up wt. = 95K, SO wt = 85K, 546 gpm = 1000 psi. Continue in hole to 5463'. CBU until mud 9.0 in and out. 500 gpm @ 1070 psi. Up wt. 110K, SO wt. 100K. Rig up Schlumberger and spot 681' +- balanced plug from 4182' to 5463'. POH 10 stands to leave stinger Q 4450'. Drop drill pipe wiper dart and pump 44 bbls to wipe drill pipe and drop plug in catcher sub. No cement back to surface, high ph H2O only. Perform hesitation squeeze as appropriate w/1000 psi maximum pressure. Pump every five minutes and bring pressure to 1000 psi during squeeze. Cement top left @ 4782' +- Formation took 3.40 bbls. Cement locked up ~ 4:45 @ 1000 psi. Expected top of cement after squeeze 4820' +-. Bleed pressure to 0 psi. Pump dry job. POH to 3-1/2" tubing stinger. RU tubing handling equipment and pull 20 jts of 3-1/2" tubing. RD tubing handling equipment. Clean rig floor. Jet BOP stack. MU test equipment and test casing/cement to 4000 psi for 30 min. PU 1.5 deg motor assy. BHA # 6. Surface test BHA # 6. PU 120 jts. of 4" drill pipe and RIH. Wash down (/4727' to 5036'. Cement stringers from 4811' to 5036'. Drilling cement f/5036' to 5245'. Drilling new hole (/5240' to 5245'. Up wt. 120K, SO wt. 100K, Rot w. 110K, 40 rpm, tq. on 5K, tq. off 5K, 304 gpm, 815 psi. Time drill 1 hr. f/5245' to 5247'. Time drill 5247' to 5260'. Backream. Displace well to 9.0 ppg. LSND mud surface to surface for FIT. FIT. 5240' MD, 4510' TVD, EMW 12.5, 9.0 ppg. mud C~ 820 psi. 05:00 - 06:00 I 1.001 STMILL I N I DPRB 06:00 - 06:30 0.50 STMILL N DPRB 06:30 - 09:00 2.50 STMILL N DPRB 09:00 - 12:00 3.00 STMILL N DPRB 12:00 - 15:00 3.00 STMILL N DPRB 15:00 - 16:30 1.50 STMILL N DPRB 16:30 - 17:00 0.50 STMILL P 17:00 - 17:30 0.50 STMILL P 17:30 - 18:30 1.00 STMILL P 18:30 - 20:30 2.00 STMILL P 20:30 - 00:00 3.50 STMILL P 9/9/2005 100:00 - 03:00 I 3.001 STMILL I P 03:00 - 04:00 I 1.001 STMILL I P 04:00 - 05:00 I 1.001 STMILL I P 05:00 - 07:00 2.00 STMILL P 07:00 - 08:30 1.50 STMILL P 08:30 - 09:30 1.00 DRILL P 09:30 - 10:30 1.00 DRILL P 10:30 - 13:00 2.50 DRILL P INTi 13:00 - 13:30 0.50 DRILL P INTi 13:30 - 19:00 5.50 DRILL P INTi 19:00 - 20:30 1.50 DRILL P INT1 20:30 - 23:30 I 3.001 DRILL I P I I INT1 23:30 - 00:00 0.50 DRILL P INT1 9/10/2005 00:00 - 02:00 2.00 DRILL P INT1 02:00 - 02:30 0.50 DRILL P INT1 02:30 - 03:00 0.50 DRILL P INT1 WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT INT1 INTi Printed: 10/10/2005 11:35:22 AM s BP Exploration Operations Summary Report Page 7 of 17 Legal Well Name: W-17 Common Well Name: W-17 Spud Date: 8/20/1988 Event Name: REENTER+COMPLETE Start: 8/20/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: ~ Description of Operations Date i~ From - To Hours Task ~ Code NPT Phase- - 9/10/2005 03:00 - 03:30 0.50 DRILL INT1 Calibrate baseline f/MWD/ECD. 03:30 - 12:00 8.50 DRILL P INT1 Directionally drill from 5260' to 5874'. PU wt. 143 K, SO wt. 110 K, Rot wt. 118K, 575 gpm @ 2350 psi, tq. on 5K tq. off 4K, 80 rpm. ADT = 7.42, AST = 4.27, ART = 3.13. ECDs = 9.80 talc./9.83 act. 12:00 - 00:00 12.00 DRILL P INT1 Drlg f/5874' to 6736'. Up wt. 150K, SO wt. 125K, Rot wt. 130K, tq. on 5K, tq. off 4K, 100 rpm, b72 gpm @ 2650 psi. ADT = 9.38, AST = 1.28, ART = 8.1 hrs. ECDs = 9.88 talc./10.02 act. 9/11/2005 00:00 - 01:00 1.00 DRILL P INT1 01:00 - 02:30 1.50 DRILL N DPRB INT1 02:30 - 03:00 0.50 DRILL N DPRB INT1 03:00 - 04:30 1.50 DRILL N DPRB INT1 04:30 - 05:00 0.50 DRILL N DPRB INTi 05:00 - 08:00 3.00 DRILL P INT1 08:00 - 12:00 I 4.001 DRILL I P I I INT1 12:00 - 17:00 I 5.001 DRILL I P I I INT1 17:00 - 18:30 I 1.501 DRILL I P I I INT1 18:30 - 21:30 I 3.001 DRILL I P I I INT1 21:30 - 23:00 I 1.501 DRILL I P I I INT1 23:00 - 00:00 I 1.001 DRILL I P I I INT1 For 24 hrs.: ADT = 16.80, AST = 5.55, ART = 11.23. Monitor well at crew change. Well making fluid. 4 bbls./5 mins. CBU. 500 gpm @ 2200 psi. MW gas cut to 8.8 ppg (0.3 ppg) Circulate out slight amount of gas. Slight amount of oil. Increased MW to 9.3 ppg Monitor well. Still making fluid. 2 bbls./ 3 min. CBU. 500 gpm @ 2200 psi. Circulate out slight amount of oil. Increased MW to 9.5 ppg Monitor well. Still making fluid. 1 bbls./3 mins. Drill from 6736' to 6927'. Increase mud wt. on the fly to 9.9+ ppg for trip margin. PU wt 153K, SO wt. 128K, Rot wt. 135K, 562 gpm, 3100 psi, tq. on 6K, tq. off 4K 100 rpm. - At first bottoms up MW cut from 9.5 ppg to 9.1 ppg - Increase MW to 9.7 ppg, flow check showing slight flow. - Increase MW to 9.9 ppg to allow for trip margin. POH. Overpull 20K @ 6755'. 25K overpull @ 6735'. Back ream (/6735 to 5779'. POH back ream f/5779' to window @ 5240'. 409 gpm, 1620 psi, 75 rpm, tq 5-11 K. Observed well breathing. CBU @ 400 gpm, 1525 psi, 50 rpm, tq 4K, monitor well, pump dry job. POH f/5240' to 213'. Monitor well @ HW DP & drill collars. Damaged top drive blower hose while removing it. Handle BHA, changeout bit to PDC DSX147GNVW and motor to 1.15 deg, clean floor. Attempt to download MWD data. No download. Change MWD download cable. No download. Schlumberger town consulted (Nate Rose). Decision made to run MWD back in hole and download at appropriate time in Schlumberger shop. 9/12/2005 00:00 - 01:00 1.00 DRILL P INT1 01:00 - 03:00 2.00 DRILL P INT1 03:00 - 04:00 1.00 DRILL P INT1 04:00 - 05:00 1.00 DRILL INT1 05:00 - 06:00 1.00 DRILL P INT1 06:00 - 00:00 I 18.001 DRILL I P I I INT1 ADT for 24 hr period = 2.27, AST = 0, ART = 2.27. RIH w/BHA # 7 to 989' and calibrate MWD. RIH w/BHA #7 to window @ 5240'. Monitor well. Service top drive. Replace top drive blower hose. RIH to 6927', washdown last stand. Drilling from 6927' to 6939' - After 2100 strokes (122 bbls) we had gas cut mud to surface (0.3 ppg) Drill directionally f/6927' to 8277'. Up wt. 180K, SO wt. 135K, Rot. wt. 150K, tq. on. 7K, tq. off 5.5K, 100 rpm, 517 gpm @ 3300 psi. Run in spike fluid and bring wt. to 10.9 ppg, add black products prior to Kingak shale penetration. Printed: 10/10/2005 1135:22 AM BP Exploration Page 8 of 17 Operations Summary Report Legal Well Name: W-17 Common Well Name: W-17 Spud Date: 8/20/1988 Event Name: REENTER+COMPLETE Start: 8/20/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date From - To Hours ' Task II, Code ~ NPT ' Phase Description of Operations 9/12/2005 06:00 - 00:00 18.00 DRILL P INTi NOTE: For 24 hr period ADT = 12.23, AST = 7.52, ART =4.71. 9/13/2005 00:00 - 00:00 24.00 DRILL P INTi Drill directionally f/ 8277' to 9710'. Up wt. 198 K, SO wt. 145 K, Rot. wt. 160 K, tq. on. 8 K, tq. off 6 K, 100 rpm, 517 gpm Q 3520 psi off btm, 3700 psi on btm. 9/14/2005 100:00 - 09:00 I 9.00) DRILL 1 P I I INT1 09:00 - 10:30 1.50 DRILL P INT1 10:30 - 15:30 5.00 DRILL P INTi 15:30 - 16:30 ~ 1.001 DRILL ~ P ~ ~ INTi 16:30 - 22:00 I 5.501 BOPSUR P I I INT1 22:00 - 23:00 I 1.001 DRILL I P I I INTi 23:00 - 23:30 0.50 DRILL P I INT1 23:30 - 00:00 0.50 DRILL P INT1 9/15/2005 00:00 - 02:00 2.00 DRILL P INTi 02:00 - 04:30 2.50 DRILL P INT1 04:30 - 09:00 4.50 DRILL P INT1 09:00 - 11:00 2.00 DRILL P INTi 11:00 - 12:00 1.00 CASE P INT1 12:00 - 20:30 8.50 CASE P INT1 20:30 - 21:00 0.50 CASE P INTi 21:00 - 22:30 1.50 CASE P INT1 22:30 - 00:00 1.50 CASE P INT1 9/16/2005 00:00 - 03:00 3.00 CASE P INT1 AST = 4.93, ART = 9.73, ADT = 14.67 Drill directionally f/ 9710' to 10,330'. 5 ft into SAG as indicated by reverse drilling break. PUW. 199 K, SOW. 147 K, Rot. wt. 160 K, TO 8 K on btm, TO 6 K off btm, 100 rpm, 517 gpm 3600 psi off btm, 3775 psi on btm. AST= 3 hrs, ART = 3.04 hrs, ADT = 6.04 Circ sweep surface to surface. Confirm SAG formation with bottoms up sample. Rack back 5 stds while circulating. POH w/ 8 1/2" bit to 9 5/8" window @ 5240' Pulled 15 - 30 k over to 8900', wiped clean OK. Once bit entered hole that 'Ghost' reamer had been thru pulled OK. MU 9 5/8" 'Storm' pkr, set same C 35'. Test same 1000 psi. OK Pull wear bushing, set test plug. RU test equip. Test BOPE to BP & AOGCC regs - 250 low / 4000 high. Test witnessed by BP Rep - L. Vaughan & NAD Rep - C. Weaver. AOGCC rep John Spalding waived witness. RD test equip. Pull test plug, install wear bushing. RIH & latch 'storm' pkr. Observe well dead. POH LD 'storm' pkr. Service TDS, grease crown. RIH w/ 8 1/2" to 6471'. Hole in good shape. Con't RIH w/ 8 1/2" bit. Hole in good shape. Circ sweep surface to surface and condition mud for running liner. 515 GPM, 3775 psi, 120 RPM, TO 8k POH w/ 8 1/2" bit to BHA. Hole in good shape. Hole fill & flow checks showing well static. LD 24 jts HWDP, & directional BHA. Clear rig floor. RU to run casing. MU &RIH w/ 7", 26#, L 80, IBT liner from pipe shed to 5,368'. PUW 145k, SOW 110k MU 7 x 9 5/8" 'Flex Lok' hanger, ZXP packer, 2 x DP pups, & 1 std of 4" DP. Circ one liner volume staging pumps up to 8 BPM @ 550 psi. PUW 130k, SOW 103k Con't RIH w/ 7", 26#, L 80, IBT liner on 4" DP from derrick to 7,894'. - Con't RIH w/ 7", 26#, L 80, IBT liner on 4" DP from derrick to 10,330'. - Wash 9,531' - 9,600' - 2 BPM @ 670 psi - Wash 9,875' - 9,950' - 2 BPM C~ 670 psi - Precaution wash 9,950' to TD C~ 10,330' - 2 BPM @ 700 psi Printed: 10/10/2005 11:35:22 AM BP Exploration Operations Summary Report Page 9 of 17 Legal Well Name: W-17 Common Well Name: W-17 Spud Date: 8/20/1988 Event Name: REENTER+COMPLETE Start: 8/20/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date I From - To-Hours Task I Code NPT Phase 9/16/2005 00:00 - 03:00 3.00 CASE P INT1 03:00 - 03:30 0.50 CEMT P INT1 03:30 - 05:30 2.00 CEMT P INTi 05:30 - 06:00 I 0.501 CEMT I P 06:00 - 08:30 I 2.501 CEMT I P 08:30 - 09:00 0.50 CEMT P 09:00 - 12:00 3.00 CEMT P 12:00 - 14:30 ~ 2.50 ~ CASE ~ P 14:30 - 17:00 I 2.501 CASE I P 17:00 - 21:30 4.50 CASE P 21:30 - 22:30 1.00 CASE P 22:30 - 23:30 1.00 CASE P 23:30 - 00:00 0.50 CASE P 9/17/2005 00:00 - 00:30 0.50 CASE P 00:30 - 02:30 2.00 CEMT P 02:30 - 05:00 I 2.501 CEMT I P 05:00 - 05:30 I 0.501 DRILL I P 05:30 - 06:00 0.50 DRILL P 06:00 - 00:00 18.00 DRILL P 9/18/2005 100:00 - 12:00 I 12.001 DRILL I P Description of Operations - MU cement head, hoses & 'Tee' - Circ & cond mud staging up to 7 BPM ~ 1375 psi. No losses. - PJSM w/ all parties for cmt job. - Dowell batch mix cmt. - Switch lines to Dowell. Test all surface equip to 4500 psi. - Pump 35 bbls 11.9 ppg Mud push followed by 148 bbls 12.5 ppg lead cement (414 sx) & 35 bbls 15.8 ppg tail cement (164 sx) w/ gasblok. - Wash up cementers via tee & hose. -Turn over to rig pumps & displace cement w/ 250 bbls 10.9 ppg mud @ 7 BPM. Bumped plug w/ 94% pump efficiency 1425 psi. Increase pump pressure to 3000 psi to set hanger. - S/O 50K on hanger to ensure hanger set. Increase pump pressure to 4500 psi to set packer. Bleed off pressure & check floats -floats holding. Rotate string 20 turns to release setting tool. Increase pump pressure from 0 to 1000 psi & pick up string 11' & increase pump rate to 360 GPM when pressure started to decrease. Circulate 40 bbls @ 360 GPM to clear cement. Slow pumps to 130 GPM & S/O 75K to ensure packer set. P/U string & S/O 25K w/ rotation @ 10 RPM to ensure packer set. - CBU to clear cement -approx. 35 bbls cement to surface. - R/D cement head,tee, valves & hoses. L/D 1 jt of 4" DP. - POH w/ 51 stands 4" DP. - Dog sub sheared. - M/U 6 1/8" drilling assembly as follows: 6 1/8" Hughes HCM505 PDC bit, 1.83 deg mud motor w/ AIM, bypass sub w! float, NM stab, NM flex LC, MWD, 3 NM flex collars, Circ sub, & jars. - P/U 72 jts 4" DP from pipeshed &RIH. - Shallow hole test MWD C~? 1058'. - RIH to 10,237' filling every 30 stands. -Slip & cut drilling line, inspect brakes, & service TD. - R/U headpin & hose. Pressure test 7" x 9 5/8" casing to 4000 psi. Chart & hold test for 30 minutes. - R/D hose &headpin. B/D lines. - Finish rigging down test equip't & M/U TD blower hose. - Tag insert landing collar on depth & drill shoe track to 5" above float shoe. 270 GPM, 1800 psi, 30 RPM, Tq 14K. -Displace well to new 8.4 ppg flo-pro mud w/ 100 bbls fresh water & 50 bbl hi-vis spacer in front of new mud. 280 GPM, 1900 psi, 35 RPM, Tq 6K. -Drill float shoe and 20' of new hole. - POH to shoe & R/U to perform FIT. - Perform FIT to 10 ppg EMW w/ 8.4 ppg flo-pro mud. (730 psi) - Drill directiona{ in 6 118" hole from 10,350' to 10,534`. Stalling out motor frequently & slow ROP in Shublik. Drilling parameters: WOB 5-10K, 300 GPM, 1600 psi, 40 RPM, on & off bottom Tq 4K, P/U wt 195K, S/O 140K, Rot wt 150K. AST 8.92 hrs, ART .2 hrs, ADT 9.12 hrs. -Drill directional in 6 1/8" hole from 10,534' to 11,192'. WOB 5-10K, 280 GPM, 1650 psi, 40 RPM, Tq on bottom 7K, Tq off INTi INT1 INT1 INTi INT1 INT1 INT1 INT1 INT1 INTi INT1 INT1 INT1 PROD1 PROD1 PROD1 PROD1 Printed: 10/10/2005 11:35:22 AM BP Exploration Page 10 of 17 Operations Summary Report Legal Well Name: W-17 Common Well Name: W-17 Spud Date: 8/20/1988 Event Name: REENTER+COMPLETE Start: 8/20/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date ', From - To Hours Task 'Code NPT Phase Description of Operations 9/18/2005 00:00 - 12:00 12.00 DRILL P PROD1 bottom 5K, P/U wt 200K, S/O wt 150K, Rot wt 165K. 12:00 - 00:00 12.00 DRILL P PROD1 -Drill directional in 6 1/8" hole from 11,192' to 11,904'. WOB 10-15K, 285 GPM 1750 psi, 40 RPM, Tq on bottom 8K, Tq off bottom 5K, P/U wt 200K, S/O wt 145K, Rot wt 165K. -ADT for last 24 hrs: AST 10.76 hrs, ART 4.92 hrs, ADT 15.68 hrs. 9/19/2005 00:00 - 06:00 6.00 DRILL P PROD1 -Drill directional in 6 1/8" hole from 11,904' to 12,500'. WOB 15K, 285 GPM, 1950 psi, 60 RPM, Tq on bottom 8K, Tq off bottom 5K, P/U wt 200K, S/O wt 140K, Rot wt 165K. 06:00 - 08:00 2.00 DRILL P PROD1 -Pump hi-vis sweep & circulate surface to surface @ 275 GPM, 1750 psi, 60 RPM. 08:00 - 10:00 2.00 DRILL P PROD1 -Monitor well - POH to shoe. Pump through tight spots @ 11,500' & 10,800'. 10:00 - 10:30 0.50 DRILL P PROD1 -RIH to bottom without any problems -hole slick. 10:30 - 13:30 3.00 DRILL P PROD1 -Pump hi-vis sweep. Circulate & condition mud @ 275 GPM, 1750 psi, 60 RPM. 13:30 - 16:00 2.50 DRILL P PROD1 - POH to 7" shoe -hole slick. - Monitor well & pump dry job. 16:00 - 18:00 2.00 DRILL P PROD1 - POH to top of 7" liner. 18:00 - 19:00 1.00 DRILL P PROD1 -Drop circ sub dart & shear open circ sub w/ 2100 psi. CBU @ 530 GPM, 770 psi. No substantial increase in cuttings on B/U. -Monitor well -pump dry job. 19:00 - 21:30 2.50 DRILL P PROD1 -Continue POH to BHA. 21:30 - 23:00 1.50 DRILL P PROD1 - UD BHA. 23:00 - 23:30 0.50 CASE P PROD1 -Clean floor & R/U to run 4 1/2" liner. 23:30 - 00:00 0.50 CASE P PROD1 - M/U 4 1/2" float shoe, 1 jt 4 1/2" 12.6# L-80 IBT-M liner, float collar, 1 jt 4 1/2" 12.6# L-80 IBT-M liner, landing collar, & 1 jt 4 ~ ~, 1/2" 12.6# L-80 IBT-M liner. Bakerlok pin ends on jts 2 & 3. Avg M/U Tq 3200 ft/Ibs. Fill pipe & check floats. 9/20/2005 00:00 - 02:00 2.00 CASE P ~ PROD1 - M/U & run 4 1/2" 12.6# L-80 IBT-M liner using BOL 2000 thread compound. Avg M/U Tq 3200 ft/Ibs. Ran a total of 55 jts w/ 52 centralizers. 02:00 - 03:00 1.00 CASE P PROD1 - M/U 5" x 7" flex lock liner hanger / C-2 ZXP packer. - RID casing handling equip't. -Circulate 1 liner volume @ 250 GPM, 140 psi, P/U wt 60K, S/O wt 60K. 03:00 - 07:00 4.00 CASE P PROD1 -Continue RIH w/ 4 1/2" liner on 4" DP breaking circulation every 10 stands. 07:00 - 08:00 1.00 CASE P PROD1 -CBU @ 7" shoe. 6 BPM, 170 psi. P/U wt 178K, S/O wt 135K. 08:00 - 09:00 1.00 CASE P PROD1 -RIH w/ 4 1/2" liner on 4" DP into open hole without any problems. 09:00 - 09:30 0.50 CASE P PRODi - M/U cement head, valves, tee, & hoses. 09:30 - i0:30 1.00 CASE P PRODi -Tag bottom on depth @ 12,500` & stage up pumps from 2 BPM to 6 BPM. FCP @ 6 BPM 170 psi. 10:30 - 12:00 1.50 CEMT P PROD1 -Pump 5 bbls water & test lines to 4000 psi. Pump 15 bbls CW-100 followed by 30 bbls 10.0 ppg Mud Push II. Pump 60 bbls (219 SX) 15.8 ppg Class G tail cement @ 5-6 BPM. Wash up cementers through tee (not on top of plug) Drop dart & displace cement with 40 bbl pert pill followed by 95 bbls of 8.5 ppg flo-pro mud. - Reciprocate string as cement going around shoe. Bump plug w/ 1480 psi & increase pressure to 3650 psi. Printed: 10/10/2005 11:35:22 AM • • BP Exploration Page ~ 1 of 17 Operations Summary Report Legal Well Name: W-17 Common W ell Name: W-17 Spud Date: 8/20/1988 Event Nam e: REENTE R+COM PLET E Start : 8/20!2005 End: Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: Rig Name: NABOB S 7ES Rig Number: Date From - To l Hours Task ( ' Code, NPT I Phase Description of Operations - 9/20/2005 ~ - 10:30 - 12:00 - 1.50 CEMT P _ _ _ PROD1 _ _ _ _ - _- __ - S/O 75K to ensure hanger set. Bleed off pressure & check floats -floats holding. - P/U to 100K & rotate string 20 turns to right. Apply 1000 psi to string & P/U string 10' circulating as pressure began to decrease. Circulate 23 bbls @ 6 BPM, 1130 psi to move cement above liner top. ' - Lower string while pumping @ 2 BPM & set down 60K to set packer. Saw an indication of shear. Repeat sequence w/ rotation C~ 15 RPM to ensure packer set. Continue pumping C~3 4 BPM 880 psi while P/U string 37' 12:00 - 13:00 1.00 CASE P PROD1 -Increase pump rate to 10.5 BPM 2130 psi once setting tool clear of packoff & circulate out cement. Approximately 20 bbls cement seen at surface. 13:00 - 13:30 0.50 CASE P PROD1 - UD cement head & 1 jt 4" DP. B/D lines. 13:30 - 16:00 2.50 CASE P PROD1 -Displace well to sea water @ 12.5 BPM 2440 psi. 16:00 - 19:00 3.00 CASE P PROD1 - POH & rack back 4" DP. 19:00 - 21:30 2.50 CASE P PROD1 - POH & UD 72 jts 4" DP 1 x 1. - UD packer setting tool. Dog sub sheared. 21:30 - 22:00 0.50 EVAL P PROD1 - R/U Schlumberger E-line. 22:00 - 00:00 2.00 EVAL P PROD1 -RIH w/ Schlumberger USIT log. 9/21/2005 00:00 - 03:00 3.00 EVAL P PROD1 -Run USIT log & R/D Schlumberger. 03:00 - 04:00 1.00 CASE P PROD1 -Pressure test 4 1/2" x 7" x 9 5/8" casing to 4000 psi. Chart & hold test for 30 minutes. - Load perforation guns in pipeshed. 04:00 - 06:00 2.00 WHSUR N CEMT PROD1 -PJSM - M/U &RIH w/ perforation guns. 06:00 - 08:00 2.00 WHSUR N CEMT ! PROD1 - C/O to 2 7/8" handling equip't. RIH w/ 49 jts 2 7/8" DP. 08:00 - 11:00 3.00 WHSUR N CEMT 'i PROD1 - C/O to 4" handling equip't &RIH w/ pert guns on 4" DP. 11:00 - 15:00 4.00 WHSUR N CEMT PROD1 - POH w/ pert guns without detonation. Determine remedial cement job required above Schrader Bluff formation. 15:00 - 18:30 3.50 WHSUR N CEMT PROD1 - C/O to 2 7/8" handling equip't & UD 49 jts 2 7/8" DP. 18:30 - 21:00 2.50 WHSUR N CEMT ' PROD1 - POH & UD perforation guns. 21:00 - 23:00 2.00 REMCM N WAIT PROD1 -Wait on Halliburton &Schlumberger & tools to arrive from Deadhorse. - R/U Schlumberger. 23:00 - 00:00 1.00 REMCM C PROD1 - RIH w/ 6.1" gauge ring & junk basket on E-line. 9/22/2005 00:00 - 01:30 1.50 REMCM P PROD1 -Continue RIH to 6000' with junk basket & 6.1"gauge ring. - POH & UD junk basket & gauge ring. Junk basket empty. 01:30 - 05:00 3.50 REMCM P PROD1 - M/U Halliburton composite bridge plug &RIH on E-line & set C~J 5,950'. - POH & R/D Schlumberger. - Close blind rams & test composite bridge plug to 1000 psi via kill line. Hold for 5 minutes. 05:00 - 10:30 5.50 REMCM P PROD1 -PJSM - P/U 15' perf gun, 40' perf blank, & 15' pert gun, & firing head &RIH on 4" DP. - Tag plug C~ 5959' DP measurement. 10:30 - 11:00 0.50 REMCM P PROD1 -Service top drive. 11:00 - 12:30 1.50 REMCM P PROD1 -Displace 8.4 sea water w/ 8.9 ppg brine w! 9 ppb Kla-Gard C~3 10.5 BPM 1200 psi. 12:30 - 14:00 1.50 REMCM P PROD1 -Space out perforation guns & go through setting sequence to fire guns. Planned shots from 5829' to 5844' & from 5884' to 5899'. (DP measurements ) 14:00 - 15:00 1.00 REMCM P PROD1 - CBU @ 9.5 GPM 1030 psi. Printed: 10/10/2005 11:35:22 AM • BP Exploration Page 12 of 17 Operations Summary Report Legal Well Name: W-17 Common Well Name: W-17 Spud Date: 8/20/1988 Event Name: REENTER+COMPLETE Start: 8/20/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date From - To ' Hours I Task I~, Code ! NPT Phase ~' _! __ 9/22/2005 14:00 - 15:00 1.00 REMCM#P PROD1 15:00 - 16:30 1.50 REMCMttP PROD1 16:30 - 19:30 3.00 REMCM P 19:30 - 21:00 1.50 REMCM P 21:00 - 22:00 1.00 REMCM P 22:00 - 00:00 2.00 REMCM P 9/23/2005 00:00 - 01:30 1.50 REMCM P 01:30 - 02:30 I 1.001 REMCMTP 02:30 - 03:30 1.00 REMCM P 03:30 - 04:30 1.00 REMCM P 04:30 - 06:30 2.00 REMCM P 06:30 - 09:00 2.50 REMCM P 09:00 - 11:30 I 2.501 R 11:30 - 12:00 0.50 R 12:00 - 14:00 2.00 R i 4:00 - 17:30 3.50 R 17:30 - 19:00 1.50 R 19:00 - 21:30 2.50 R 21:30 - 00:00 I 2.501 R PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Description of Operations - Monitor well -well flowing. - Raise MW to 9.0 ppg & circulate surface to surface . - Monitor well -static. - POH w/ perforating guns. - PJSM - UD perforating guns. All shots fired as planned. -Clean rig floor. - Monitor welt/ -well flowing (trickling down flowline) - M/U EZSV & setting tool. - RIH w/ EZSV on DP to 4790'. - RIH & tag bridge plug @ 5959'. P/U string 95' & set EZSV C~3 5864' with 35 right hand turns. Unsting from EZSV. - Hole did not take proper fill on TIH & flowing, Raise MW to 9.2 ppg & circulate surface to surface. Traces of oil in brine on B/U. - Monitor well -static - Sting back into EZSV & establish circulation through perforations. Maximum pump rate achieved - 1.5 BPM 700 psi. Fluctuating pressures & returns while pumping. Kept pressures below 12.5 EMW by adjusting pump rates. - PJSM -Test lines to 3000 psi & pump 5 bbls CW-100 followed by 15 bbls 15.8 ppg Class G cement. Flush lines w/ 5 bbls water & displace cement w/ 51.4 bbls 9.2 ppg brine. Held 130 to 190 psi back pressure on annulus by having annular preventer closed & operating choke throughout cement job & displacement. - Initial displacement of cement w/ rig pumps @ 2 BPM, 300 psi. - Final displacement of cement 1.5 BPM, 480 psi. Lost 4 bbls to formation while displacing. - Under displace cement by 2 bbls. PROD1 -Unsting from EZSV & P/U string 305' to 5559'. Reverse circulate DP volume @ 4 BPM, 650 psi. 2 bbls of cement returns. - Pressure up annulus to 200 psi & held for 5 min. - Bleed off pressure to zero. Fluid u-tubing up DP. Circulate to balance. PROD1 -Pull 2 stands -close annular preventer & pressure up 200 psi & hold. PROD1 -Bleed off pressure -monitor well & POH. UD EZSV setting tool & stinger. PROD1 -Service TD & lubricate rig. PROD1 - M/U BHA. Used 6 1/8" XR+ Smith bit, 3 boot baskets, bit sub with float, 9 each 4 3/4" drill collers, 2 jts HWDP, jars, 3 HWDP and XO. PROD1 -RIH with clean out BHA to 5541'. PROD1 -Slip and cut drilling line 104'. PROD1 -Tag cement @ 5549'. Drill cement to EZSV C~3 5862'. WOB 5K, 10 BPM, 1700 psi, 60 RPM, Tq on bottom 3K, Tq off bottom 2.5K. PROD1 -Drilling on EZSV trying different drilling parameters. WOB 5-20K, 8 BPM 1150 psi, 50-90 RPM, Printed: 10/10/2005 11:35:22 AM • • BP Exploration Page 13 of 17 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: W-17 W-17 Spud Date: 8/20/1988 REENTER+COMPLETE Start: 8/20/2005 End: NABOBS ALASKA DRILLING I Rig Release: NABOBS 7ES Rig Number: Date I From - To Hours I Task Code 9/23/2005 21:30 - 00:00 9/24/2005 00:00 - 01:30 2.50 REMCM P 1.50 REMCMTP 01:30 - 03:30 2.001 R NPT ' Phase ' Description of Operations PROD1 Tq on bottom 3-5K. PROD1 -Drill EZSV cementing retainer w/ various drilling parameters - WOB 5-20K, 8 BPM, 1150 psi, 50-80 RPM, Tq on bottom 3-5K. PROD1 -Drill cement /junk from 5866' to 5958' pumping hi-vis sweeps as needed. 03:30 - 05:00 1.50 REMCM P PROD1 -Tag composite bridge plug on depth at 5959'. Drill up plug w/ ', various drilling parameters: WOB 10-20K, 8 BPM 1175 psi, Tq on bottom 3-5K. Pumping hi-vis sweeps as needed. 05:00 - 07:30 2.50 REMCM P PROD1 -RIH pushing junk to 10,.033' 07:30 - 10:00 2.50 REMCM P PROD1 -Circulate surface to surface x 2 to get MW balanced to 9.1 Ppg• 10:00 - 14:00 4.00 REMCM P PROD1 -Monitor well -pull 5 stands. - Pump dry job & POH to BHA. 14:00 - 15:30 1.50 REMCM P PROD1 - L/D BHA & clear floor. 15:30 - 16:30 1.00 REMCM P PROD1 -Bring Schlumberger tools to rig floor. PJSM & R/U E-line 16:30 - 21:00 4.50 REMCM P PROD1 - USIT log from 6200' to 5500'. Discuss results w/ Anchorage Team - no further cement squeezing required. - R/D Schlumberger -well flowing (1.5 bbls/hr while logging - traces of oil in trip tank) 21:00 - 22:00 1.00 REMCM P PROD1 - R/U to run 2 3/8" DP. 22:00 - 23:30 1.50 REMCM P PROD1 - M/U 3.79" flat bottom mill, 2 each 3 1/2" boot baskets, bit sub, 3 steel DC's, & XO. 23:30 - 00:00 0.50 REMCM P PRODi -RIH picking up 2 3/8" SLH-90 DP 1 x 1. 9/25/2005 00:00 - 01:30 1.50 REMCM P PROD1 - RIH to 2530' picking up 2 3/8" DP 1 x 1. 01:30 - 03:00 1.50 REMCM P PRODi -Change out to 4" handling equipment &RIH w/ 4" DP. 03:00 - 04:30 1.50 REMCM P PROD1 - RIH to below lowest perforations C~ 5899' & circulate 9.2 ppg brine surface to surface C~? 230 GPM, 3400 psi. Traces of oil in brine while circulating until bottoms up. 04:30 - 06:00 1.50 REMCM P PROD1 -RIH & tag junk on top of 4 1/2" liner @ 10178'. 06:00 - 08:30 2.50 REMCM P PROD1 -Mill on junk from 10178' to bottom of tie-back sleeve @ 10190'. 1-2K WOM, 40 RPM, 200 GPM, 2800 psi, Tq off bottom 5.4K, Tq on bottom 6.3K. ', 08:30 - 10:30 2.00 REMCM P PROD1 - RIH w/ milling ass'y to 4 1/2" landing collar C 12411'. ~ 10:30 - 13:00 2.50 REMCM P PROD1 -Pump & circulate out hi-vis sweep C~? 210 GPM, 3250 psi. 13:00 - 14:30 1.50 REMCM P PROD1 -Pump dry job & POH to 10720'. 14:30 - 15:00 0.50 REMCM P PROD1 -Pulled tight. Make up top drive. Set weight down and rotate while circulating and work through tight spot at 10,720'. 125 GPM, 1800 psi. 20K drag through tight spot. 15:00 - 16:00 1.00 REMCM N RREP PROD1 - RIH to 10720' & change out grabber dies on top drive pipe handler. 16:00 - 16:30 0.50 REMCM P PROD1 - POH to 10657' & monitor well. Well flowing. 16:30 - 17:30 1.00 REMCM P PROD1 - POH to 10150' to above top of 4 1/2" liner. While pulling to top of the 4 1/2" liner worked pipe past tight spots and high drag several times each stand while inside of 4 1/2" liner from ~ 10,720' to 10179'. ', 17:30 - 19:30 2.00 REMCM P PROD1 -increase weight of brine to 9.5 ppg @ 210 GPM, 2760 psi. 19:30 - 20:00 0.50 CASE P PROD1 -Monitor well -still flowing. Circulate additional 15 minutes & monitor well -still flowing. 20:00 - 22:00 2.00 REMCM P PROD1 -Increase weight of brine to 9.7 ppg @ 235 GPM, 3450 psi. 22:00 - 22:30 0.50 REMCM P PROD1 -Monitor well -pull 5 stands -monitor well. Well static. 22:30 - 00:00 1.50 REMCM P PROD1 - POH to 6800'. 9/26/2005 00:00 - 01:30 1.50 REMCM P PRODi - POH to 2 3/8" DP @ 2530' Printed: 10/10/2005 11:35:22 AM • • BP Exploration Page 14 of 17 Operations Summary Report Legal Well Name: W-17 Common Well Name: W-17 Spud Date: 8/20/1988 Event Name: REENTER+COMPLETE Start: 8/20/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date ~~ From - To Hours Task Code NPT ' Phase Description of Operations 9/26/2005 01:30 - 02:00 0.50 REMCM P PRODi - C/O to 2 3/8" handling equip't. 02:00 - 05:00 3.00 REMCM P PROD1 - POH & UD 2 3/8" DP 1 x 1. 05:00 - 05:30 0.50 REMCM P PROD1 - UD BHA. Recovered 3 lbs. of meta! & plastic from boot baskets. 05:30 - 06:00 0.50 CASE P PROD1 - R/D 2 3/8" handling equip't. Clean & clear floor. 06:00 - 10:30 4.50 REMCM P PROD1 - P/U 5.19" polish mill, XO, drill pipe spacer, 5.93" liner top dressing mill, & DP pup jt &RIH w/ 4" DP. 10:30 - 11:00 0.50 REMCM P PROD1 -Tag up @ 10,188'. WOM 6-8K, 4 BPM, 470 psi, 90 RPM, Tq off bottom 7.1 K, Tq on bottom 8K. Stroke mill length of tie back sleeve x 5. 11:00 - 13:00 2.00 REMCM P PROD1 - P/U above 4 1/2" liner top & CBU @ 5 BPM, 500 psi. 13:00 - 16:30 3.50 REMCM P PRODi - POH wJ 4" DP & rack back 81 stands. 16:30 - 18:30 2.00 REMCM P PROD1 - POH & UD 4" DP 1 x 1. 18:30 - 19:00 0.50 REMCM P PROD1 -Brass tattle tail on dressing mill unscathed indicating mill never saw the top of the 4 1/2" liner. 19:00 - 19:30 0.50 REMCM N DPRB PROD1 -Load pipeshed w/ 4" DP. 19:30 - 23:00 3.50 REMCM N DPRB PROD1 - P/U DP 1 x 1 &RIH while waiting on additional tools to arrive from Deadhorse.POH & rack back in stands. 23:00 - 00:00 1.00 REMCM N DPRB PROD1 - M/U BHA as follows: 4.25" junk mill, XO, 2 weight bars, 5.19" polish mill, XO, DP pup, 5.93" top dress mill, DP pup jt, XO, 3 boot baskets, bit sub, & XO. 9/27/2005 00:00 - 03:30 3.50 REMCM N DPRB PROD1 -RIH with 4 1/4" pilot mill and liner top PBR polishing mill assembly on 4" DP. 03:30 - 07:00 3.50 REMCM N DPRB PROD1 -Tag up on junk @ 10,184' & mill w/ various parameters. WOM 5-10K, 1-5 BPM, 400-1800 psi, 45-55 RPM, Tq off bottom 8K, Tq on bottom 8.5-9.5K. Indications that mill is not entering liner. 07:00 - 10:30 3.50 REMCM N DPRB ' PROD1 Monitor well. Pump dry job. POH. 11:30 - 12:00 0.50 REMCM N DPRB PROD1 Lay down BHA. Recovered bottom section of 7" FasDrill bridge plug stuck on 4 114" miN. Clean junk baskets and floor. 12:00 - 12:30 0.50 REMCM N DPRB PROD1 Pick up liner top PBR polish mill BHA. 12:30 - 15:30 3.00 REMCM N DPRB PROD1 RIH w/polish mill assembly to 10171'. 15:30 - 16:30 1.00 REMCM N DPRB PROD1 MU topdrive. RIH and tag at 10184'. Break circulation and i pump 5 bpm @ 500 psi, rot. 30 rpm, tq. 7.2K on, up wt. 210K, SO wt. 132K, rot. wt. 165K. Polish liner top and PBR. Tq. inside of PBR = 8K. 16:30 - 17:30 1.00 REMCM N DPRB PROD1 Circulate bottoms up at 9 bpm with 1500 psi. 17:30 - 19:00 1.50 REMCM N DPRB PROD1 Monitor well. Flow observed. Circulate and weight up brine to 9.9 pP9• 19:00 - 22:30 3.50 REMCM N DPRB PRODi Monitor well, static. Pump dry job and POH with 84 stands. 22:30 - 00:00 1.50 REMCM N DPRB PROD1 POH and lay down 69 jts. of 4" HT-40 drill pipe. 9/28/2005 00:00 - 02:00 2.00 REMCM N DPRB PROD1 Lay down 4" drill pipe and BHA. Note: brass tattle tale indicators on polish mill indicated that tool had entered tieback ~ sleeve and bottomed out at proper depth. 02:00 - 02:30 0.50 REMCM N • CEMT PROD1 Rig up 4-1/2" casing running equipment to run 4-1/2" tieback (liner. 02:30 - 06:00 3.50 REMCM N CEMT PROD1 PJSM. Baker-Lok tie back stem and shoe track. Run 4-1/2" ~i IBT-M 12.60 IbJft. liner filling while running in hole. Find one bad joint and replace same. 06:00 - 07:00 1.00 REMCM N CEMT PROD1 RD casing handling equipment, clear floor and RU to run drill pipe. 07:00 - 07:30 0.50 REMCM N CEMT PROD1 Circulate one liner volume. Check up and down weights. 07:30 - 09:30 2.00 REMCM N CEMT PROD1 RIH to liner top w/tie back stem. Printed: 10/10/2005 11:35:22 AM • BP Exploration Operations Summary Report Legal Well Name: W-17 Common Well Name: W-17 Event Name: REENTER+COMPLETE Start: 8/20/2005 Contractor Name: NABOBS ALASKA DRILLING 1 Rig Release: Rig Name: NABOBS 7ES Rig Number: Date ' From~To li Hours Task I Code NPT I' Phase 9/28/2005 09:30 - 10:30 ~ 1.00 ~ REMCMT II N CEMT ~ PROD1 10:30 - 11:00 0.50 REMCM N CEMT PROD1 11:00 - 12:00 1.00 REMCM N CEMT PROD1 12:00 - 12:15 0.25 REMCM N CEMT PROD1 12:15 - 13:00 0.75 REMCM N CEMT PROD1 13:00 - 13:30 0.50 REMCM N CEMT PROD1 13:30 - 14:30 1.00 REMCM N CEMT PROD1 14:30 - 15:00 0.50 REMCM N CEMT PROD1 15:00 - 18:00 3.00 REMCM N CEMT PROD1 18:00 - 19:00 I 1.001 BOPSUR P I I PROD1 19:00 - 23:30 1 4.501 BOPSUR P I I PROD1 23:30 - 00:00 0.50 BOPSU P PROD1 9/29/2005 00:00 - 01:30 1.50 BOPSU N PROD1 01:30 - 03:30 2.00 BOPSU P PROD1 03:30 - 04:00 0.50 BOPSU P PROD1 04:00 - 05:30 1.50 CLEAN P CLEAN 05:30 - 17:30 12.00 CLEAN N CEMT CLEAN i 17:30 - 18:00 0.50 CLEAN N CEMT CLEAN 18:00 - 20:00 2.00 CLEAN N CEMT CLEAN 20:00 - 22:00 2.00 CLEAN N CEMT CLEAN 22:00 - 00:00 2.00 CLEAN N CEMT CLEAN 9/30/2005 100:00 - 01:30 I 1.501 CLEAN I N I CEMT I CLEAN 01:30 - 05:00 3.50 CLEAN N CEMT CLEAN Page 15 of 17 Spud Date: 8/20/1988 End: Description of Operations Pressure against seals to confirm sting in. PU and space out cementing ports above tieback stem. Pump 5 bpm G 815 psi. PU wt. 190K, SO wt. 120K. PJSM w/Schlumberger, all hands and WSL. Batch mix cement. Circulate 9.9 ppg gal brine. Pump 5 bbls water and pressure test lines to 4500 psi. Pump 10 bbls of 12.3 ppg mudpush, 86.5 bbls 15.8 ppg Class G cement w/Schlumberger @ 5.3 bpm. Drop drill pipe wiper plug. Displace 119 bbls. 9.9 ppg brine w/ rig pumps C~3 5 bpm C~ 1300 psi. Slow to 2 bbls/min before plug bump. Bump plug w/1469 psi. Cement in place @ 13:00. SO and sting tie back stem into extension sleeve. Bleed off pressure on drill pipe and check for flow back. No flow back. Tieback in place. Pressure up to 4000 psi and set liner hanger. Bleed off pressure. SO liner wt. plus 20K lbs. Hanger set. Pressure to 1000 psi. Release liner running tools, pressure bled to 0 psi. Set 45 K lbs. down on liner top and rotate slowly w/rotating dog sub to set ZXP packer w/top of liner Q 5721'. CBU @ 5 bpm, 380 psi. 2 bbls. cement to surface. Lay down cement head and blow down lines. POH & LD liner running tools. Indicator screws on Rotating Dog Sub sheared. Pull wear bushing and rig up for BOP test. Run in all lock downs on test plug. Pressure test BOP. 250 psi low side test, 4000 psi high side test. 2500 psi on annular preventer. Test witnessed by AOGCC rep. John Crisp, Nabors tourpusher and BP WSL. LD 4" test jt. b/d lines. Install and test 2-3/8" rams. RU and test 2-3/8" dart valve~rlW valve, upper 2-3/8" pipe rams to 250 psi low and 4000 psi high. Test annular 250 psi low and 4000 psi high. Test witnessed by John Crisp AOGCC representative, Nabors tour pusher -Ray Barnes ,and BP WSL -Lowell Anderson. RD testing equipment. Rig service, lubricate topdrive. Cut and slip 83' of drilling line. PU 3-3/4" clean out BHA consisting of 3.75" PDC bit, Baker 2-7/8" motor, pump out sub, Hi-Load disconnect, float sub, x-overs 2 ea. Pick up 227 joints 2-3/8" drill pipe and TIH w/cleanout BHA. RD 2-3/8" equipment and PU 4" equipment. RIH to 9989'. Taking wt.- MU topdrive. Wash down and find landing collar solid C~? 10128'. Drill on landing collar f/ 10128' to 10173'. Up wt. 125K, SO wt. 95K., rot. wt. 100, 10 rpm, WOB 1 K, tq. on 2200 ft. lbs., 110 gpm, 1325 psi off, 1550 psi on. RU test equipment. Pressure test tie back liner to 4000 psi held for 30 minutes. Test ok. Drill plug, landing collar cement and float collar from 10128' to 10205'. Up wt. 125K, SO wt. 95K., rot. wt. 100, 17 rpm, tq. on 2200 ft. lbs., 110 gpm, WOB 1 K, 1325 psi off, 1538 psi on. Stuck briefly at 10170'. Work pipe, rotate, circulate. Pipe free. No further trouble. Printed: 10/10/2005 11:35:22 AM • • BP Exploration Page 16 of 17 Operations Summary Report Legal Well Name: W-17 Common Well Name: W-17 Spud Date: 8/20/1988 Event Name: REENTER+COMPLETE Start: 8/20/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: 9/30/2005 ~ 05:00 - 08:00 3.00 CLEAN N CEMT CLEAN RIH. Taking weight on connections @ 10,500'. Circulate bottoms up, 84 gpm, 10 rpm. No junk or cement across shakers after circulating. 08:00 - 12:00 4.00 CLEAN N CEMT CLEAN RIH. Continue washing down to 12411'. 12:00 - 13:00 1.00 CLEAN N CEMT CLEAN RU and test 4 1/2" liner, 4 1/2" tie-back liner, 7" liner and 9 5/8" casing to 4000 psi f/12411' to surface. Hold 30 minutes and chart. Test held. Rig down test equipment. 13:00 - 15:00 2.00 CLEAN N CEMT CLEAN Drop 3/4" ball to open circ. sub. Pump sweep and circulate bottoms up at 5 bpm, 3900 psi, UP wt. 165K, SO 100K. Little debris seen across shakers with sweep. 15:00 - 18:00 3.00 CLEAN N CEMT CLEAN Displace brine in hole to 8.4 ppg seawater and spot 35 bbl. pert pill across pert interval in 4 1/2 liner at 210 gpm @ 3875 psi. 18:00 - 21:00 3.00 CLEAN N CEMT CLEAN POH to 7300'. No trouble. 21:00 - 22:30 1.50 CLEAN N CEMT CLEAN Change over toools from 4" to handle 2-3/8" drillpipe and POH to 5721'. 22:30 - 00:00 1.50 CLEAN N CEMT CLEAN Work pipe across 4 1!2" liner top 70 K UP wt., 55K SO wt. Circulate bottoms up to clean up 4-1/2" x 7" liner top. 273 gpm @ 3900 psi. 10/1/2005 00:00 - 02:00 2.00 CLEAN N CEMT CLEAN POH to 4933' top of 7" x 9-5/8" liner top. Work pipe across liner top and circulate bottoms up w/8.5 ppg. seawater at 250 gpm, 3880 psi. Nothing across shakers with circulation. 02:00 - 05:00 3.00 CLEAN N CEMT CLEAN POH and stand back 76 stands of 2-3l8" drill pipe and lay down BHA #13, 3 3/4" bit and 2 7/8" mud motor. Clear rig floor. 05:00 - 06:00 1.00 PERFO P OTHCMP PJSM with Schlumberger crew, all hands, tourpusher, WSL. Rig up to run pert. guns. 06:00 - 07:30 1.50 PERFO P OTHCMP RIH with 790' of Schlumberger 2.88" HSD TCP guns, eFire pressure actuated firing head, PJ2906 charges with 4 shots/tt. spacing. 07:30 - 15:30 8.00 PERFO P OTHCMP RIH and tag 4 1/2" landing collar at 12446'. Pick up and spaceout at pert depth with nose of TCP assyembly at 12080'. Up wt. 155K, SO wt. 95K. 15:30 - 16:00 0.50 PERFO P OTHCMP PJSM. Perform pump pressure firing sequence on eFire firing system as per Schlumberger rep. Guns fired. 11 bbl. fluid loss recorded. 16:00 - 16:30 0.50 PERFO P OTHCMP POH guns to above perfs to 11236'. 1fi:30 - 18:00 1.50 PERFO P OTHCMP Circulate bottoms up with 8.5 ppg. seawater (~ 5 bpm, 3875 psi. 18:00 - 21:00 3.00 PERFO P OTHCMP Monitor well and see slight loss. Pump dry job and blow down lines. POH laying down 105 jts. of 4" drillpipe. 21:00 - 00:00 3.00 PERFO P OTHCMP Change handling tools and equipment from 4" to 2-3/8". POH laying down 2-3/8" drill pipe. 10/2/2005 00:00 - 03:00 3.00 PERFO P OTHCMP POH and LD 2-318" drill pipe. 03:00 - 06:00 3.00 PERFO P OTHCMP PJSM. POH and lay down eFire firing head and thirty seven 2.88" Schlumberger TCP guns. All charges fired and all fired within scallops. 06:00 - 08:00 2.00 BOPSU P W HDTRE Pull wear bushing and clear rig floor. 08:00 - 15:00 7.00 BUNCO RUNCMP RIH w/4-1/2" 12.60 Ib./ft, L-80 TC-II tubing, S-3 permanent packer and completion equipment. 15:00 - 17:00 2.00 BUNCO RUNCMP Run in lock down screws and RU to reverse circulate. 17:00 - 18:30 1.50 BUNCO RUNCMP Reverse circulate 89 bbls. corrosion inhibited seawater followed by 190 bbls. of 8.5 ppg seawater. Pump C 3 bpm, 50 Date From - To ~ Hour Task :Code I~' NPT Phase ~ Description of Operations Printed: 10/10/2005 11:35:22 AM • BP Exploration Page 17 of 17 Operations Summary Report Legal Well Name: W-17 Common Well Name: W-17 Spud Date: 8/20/1988 Event Name: REENTER+COMPLETE Start: 8/20/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date From - To I~ Hours ~ Task I~ Code II NPT Phase '' Description of Operations 10/2/2005 17:00 - 18:30 1.50 BUNCO RUNCMP psi. 18:30 - 20:30 2.00 BUNCO RUNCMP Drop ball and rod down tubing to RHC plug seat in XN nipple @5716'. Set packer and test tubing by pressuring tubing to 4000 psi for 30 min. with chart. Bleed off pressure on tubing to 1500 psi. Pressure annulus to 4000 psi for 30 min. with chart. Bleed off tubing pressure and pressure annulus to 2500 psi and see the DCK valve shear at that pressure. Pump 2 bbls down tubing and then 2 bbls down annulus to confirm DCK shear out. 20:30 - 21:00 0.50 BOPSU P RUNCMP Install Two Way Check Valve and test to 1000 psi below valve. 21:00 - 00:00 3.00 BOPSU P RUNCMP Nipple down BOP stack. Open doors and remove rams. Clean cavities for annual inspection. Stand BOP back on stump. 10/3/2005 00:00 - 01:00 1.00 BOPSU P RUNCMP Continue to nipple down BOP stack. 01:00 - 04:00 3.00 WHSUR P RUNCMP NU adaptor and tree. Test tree and packoff to 5000 psi. 04:00 - 05:30 1.50 WHSUR P RUNCMP RU Drill Site Maintenance lubricator and pull TWC. 05:30 - 08:00 2.50 WHSUR P RUNCMP Reverse circulate 155 bbls. diesel to annulus. 1.5 bpm C~3 1500 psi. U-tube annulus to tubing until diesel is equalized. 08:00 - 10:00 2.00 WHSUR P RUNCMP RD circulation lines. RU drill site maintenance and install BPV. ~ Test BPV to 1000 psi for 10 mins. RD drill site maintenance lubricator. Install tree cap and gauges. Clean cellar. Move pit module away from sub structure. Prepare for rig move. Release rig at 10:00. Printed: 10/10/2005 11:35:22 AM ~'tr? ... .. ~ .. _ Schiumheraer vv--~ i H au Report Date: 19-Sep-05 Client: BP Exploration Alaska Field: Prudhoe Bay Unit- WOA Structure I Slot: W-PAD I W-17 Well: W-17 Borehole: W-17A UWIIAPI#: 500292186501 Survey Name 1 Date: W-17A /September 19, 2005 Tort 1 AHD 1 DDI 1 ERD ratio: 256.925° 16844.21 ft 16.385 10.755 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 7017 53.776, W 149 5 33.279 Location Grid NIE YIX: N 5959490.040 ftUS, E 612049.030 ftUS Grid Convergence Angle: {0.85431046° rcepvrt Vertical Section Azimuth: 92.110° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 84.56 ft relative to MSL Sea Bed 1 Ground Level Elevation: 52.77 ft relative to MSL Magnetic Declination: 24.584° Total Field Strength: 57583.278 nT Magnetic Dip: 80.837° Declination Date: September 10, 2005 Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corr Mag North •> True North: +24.584° Comments Measured inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Fasting Latitude Longitude Depth Section Departure . ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS r(IC U.VV V.VV U.VU -64.Vb GCT MS 22.96 0.00 0.00 -61.60 26.86 0.13 71.16 -57.70 41.46 0.10 116.62 -43.10 56.06 0.17 152.80 -28.50 70.76 0.28 141.48 -13.80 85.36 0.30 138.60 0.80 100.06 0.28 136.56 15.50 114.66 0.27 138.71 30.10 129.26 0.22 147.15 44.70 143.86 158.46 173.16 187.76 202.36 216.96 231.56 246.26 260.56 274.96 289.36 303.76 318.06 U.VU U.UU U.UU U.UU U.UU U.UU b96949U.V4 li1LU49.U3 N 7U 1 / 53.776 W 149 5 33.279 0.00 0.00 0.00 0.00 0.00 0.00 5959490.04 612049.03 N 70 17 53.776 W 149 5 33.279 0.00 0.00 0.00 0.00 0.00 3.33 5959490.04 612049.03 N 70 17 53.776 W 149 5 33.279 0.03 0.03 0.03 0.00 0.03 0.64 5959490.04 612049.06 N 70 17 53.776 W 149 5 33.278 0.05 0.07 0.06 -0.02 0.05 0.73 5959490.02 612049.08 N 70 17 53.776 W 149 5 33.277 0.09 0.12 0.11 -0.07 0.08 0.80 5959489.97 612049.12 N 70 17 53.776 W 149 5 33.277 0.14 0.20 0.18 -0.13 0.13 0.17 5959489.91 612049.16 N 70 17 53.775 W 149 5 33.275 0.19 0.27 0.26 -0.18 0.18 0.15 5959489.86 612049.22 N 70 17 53.774 W 149 5 33.274 0.24 0.34 0.33 -0.23 0.23 0.10 5959489.81 612049.26 N 70 17 53.774 W 149 5 33.272 0.28 0.40 0.39 -0.28 0.27 0.42 5959489.76 612049.30 N 70 17 53.773 W 149 5 33.271 0.30 0.45 0.44 -0.33 0.29 0.41 5959489.72 612049.33 N 70 17 53.773 W 149 5 0.31 0.50 0.48 -0.37 0.30 0.33 5959489.67 612049.34 N 70 17 53.773 W 149 5 0.32 0.53 0.51 -0.41 0.30 0.08 5959489.64 612049.34 N 70 17 53.772 W 149 5 3 0 0.32 0.58 0.54 -0.45 0.31 0.18 5959489.60 612049.34 N 70 17 53.772 W 149 5 33.270 0.34 0.62 0.59 -0.49 0.32 0.23 5959489.55 612049.36 N 70 17 53.771 W 149 5 33.270 0.36 0.67 0.63 -0.54 0.34 0.24 5959489.51 612049.38 N 70 17 53.771 W 149 5 33.269 0.38 0.72 0.68 -0.58 0.36 0.22 5959489.47 612049.40 N 70 17 53.771 W 149 5 33.268 0.40 0.75 0.72 -0.61 0.38 0.40 5959489.44 612049.42 N 70 17 53.770 W 149 5 33.268 0.41 0.78 0.74 -0.64 0.38 0.34 5959489.41 612049.42 N 70 17 53.770 W 149 5 33.268 0.40 0.80 0.76 -O.ti6 0.38 0.09 5959489.38 612049.42 N 70 17 53.770 W 149 5 33.268 ' 0.40 0.83 0.79 -0.69 0.38 0.29 5959489.36 612049.42 N 70 17 53.770 W 149 5 33.268 0.42 0.86 0.82 -0.72 0.39 0.31 5959489.33 612049.43 N 70 17 53.769 W 149 5 33.268 0.43 0.89 0.84 -0.74 0.40 0.19 5959489.30 612049.44 N 70 17 53.769 W 149 5 33.267 SurveyEditor Ver SP 1.0 Bld( doc40x_56) W-17\W-17\W-17A\W-17A Generated 9/26/2005 1:52 PM Page 1 of 9 0.18 0.15 0.15 0.17 0.18 0.20 0.17 0.12 0.10 0.10 0.12 0.12 0.10 160.08 172.97 177.65 171.21 160.77 V.UV 22.96 26.86 41.46 56.06 70.76 85.36 100.06 114.66 129.26 143.86 158.46 173.16 187.76 202.36 152.04 132.40 216.96 148.45 147.00 231.56 160.36 161.70 246.26 183.33 176.00 260.56 190.61 190.40 274.96 171.68 204.80 289.36 150.30 219.20 303.76 160.04 233.50 318.06 59.30 73.90 88.60 103.20 117.80 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude - Depth Section Departure ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS JJL.wO U. IU IOL.V/ 346.86 0.17 184.42 361.16 0.17 179.44 375.56 0.13 165.90 389.96 0.13 151.79 404.36 0.15 152.55 418.76 0.17 163.49 433.16 447.46 461.96 476.26 490.66 505.06 519.46 533.96 548.36 562.76 577.16 591.56 605.86 620.36 634.66 649.06 663.56 677.96 692.26 706.76 721.16 735.56 749.96 764.36 778.86 793.26 807.66 822.16 836.56 850.96 865.36 879.86 894.26 908.66 0.17 0.15 0.17 0.17 0.20 0.22 0.20 0.20 0.22 0.22 0.20 0.18 0.15 0.17 0.18 0.20 0.20 0.15 0.18 0.18 0.15 0.15 0.12 0.13 0.17 0.12 0.12 0.13 0.10 0.05 0.03 0.03 0.05 0.05 178.96 185.16 177.78 161.27 150.42 152.88 167.23 181.01 179.09 167.86 154.77 149.32 157.50 172.49 172.40 160.09 147.49 145.10 154.49 169.07 186.13 186.67 176.98 171.16 169.48 189.18 199.81 191.51 191.19 184.37 181.27 187.54 205.57 209.99 cw/.au 262.30 276.60 291.00 305.40 319.80 334.20 348.60 362.90 377.40 391.70 406.10 33L.40 346.86 361.16 375.56 389.96 404.36 418.76 433.16 447.46 461.96 476.26 490.66 U.43 0.43 0.43 0.44 0.45 0.47 0.48 0.49 0.49 0.49 0.50 0.52 U.`JI V.i3/ -U.// V.4U V.L/ 5`J5`J42f`J.L25 0.95 0.90 -0.80 0.40 0.49 5959489.25 0.99 0.93 -0.84 1.03 0.97 -0.88 1.06 1.00 -0.91 1.10 1.04 -0.94 1.14 1.08 -0.98 1.18 1.12 -1.02 1.22 1.15 -1.06 1.26 1.19 -1.10 1.30 1.23 -1.14 1.35 1.28 -1.18 0.40 0.41 0.42 0.43 0.45 0.45 0.45 0.45 0.46 0.48 0.50 0.52 0.53 0.53 0.53 0.10 5959489.20 0.37 5959489.17 0.22 5959489.14 0.14 5959489.11 0.25 5959489.07 0.32 5959489.03 0.18 5959488.99 0.20 5959488.95 0.34 5959488.91 0.32 5959488.86 0.15 5959488.82 0.39 5959488.77 0.33 5959488.72 0.15 5959488.67 0.30 5959488.61 0.36 5959488.56 0.19 5959488.52 0.27 5959488.48 0.32 5959488.45 0.07 5959488.40 420.50 505.06 0.55 1.40 1.33 -1.23 434.90 519.46 0.57 1.45 1.38 -1.28 449.40 533.96 0.58 1.50 1.43 -1.33 463.80 548.36 0.58 1.56 1.48 -1.38 478.20 562.76 0.59 1.61 1.53 -1.44 492.60 577.16 0.60 1.66 1.58 -1.49 507.00 591.56 0.63 1.71 1.63 -1.53 521.30 605.86 0.65 1.75 1.67 -1.56 535.80 620.36 0.66 1.79 1.71 -1.60 550.10 634.66 0.67 1.84 1.76 -1.65 564.50 649.06 0.68 1.88 1.80 -1.69 579.00 663.56 0.70 1.93 1.85 -1.74 593.40 677.96 0.73 1.98 1.90 -1.77 607.70 692.26 0.75 2.02 1.94 -1.81 622.20 706.76 0.77 2.06 1.98 -1.85 636.60 721.16 0.77 2.11 2.02 -1.89 651.00 735.56 0.77 2.14 2.05 -1.93 665.40 749.96 0.77 2.18 2.09 -1.97 679.80 764.36 0.77 2.21 2.12 -2.00 694.30 778.86 0.78 2.25 2.15 -2.03 708.70 793.26 0.78 2.28 2.19 -2.07 723.10 807.66 0.78 2.31 2.21 -2.10 737.60 822.16 0.77 2.34 2.24 -2.13 752.00 836.56 0.76 2.37 2.26 -2.16 766.40 850.96 0.76 2.39 2.28 -2.18 780.80 865.36 0.76 2.40 2.29 -2.19 795.30 879.86 0.76 2.41 2.30 -2.19 809.70 894.26 0.76 2.42 2.31 -2.20 824.10 908.66 0.75 2.43 2.31 -2.21 0.55 0.57 0.59 0.60 0.61 0.62 0.64 0.67 0.69 0.70 0.70 0.70 0.70 0.70 0.71 0.71 0.70 0.69 0.69 0.68 0.68 0.68 0.68 0.67 0.31 5959488.36 0.30 5959488.31 0.35 5959488.28 0.28 5959488.24 0.32 5959488.20 0.40 5959488.16 0.01 5959488.12 0.26 5959488.09 0.11 5959488.05 0.28 5959488.02 0.49 5959487.98 0.15 5959487.95 0.14 5959487.92 0.21 5959487.89 0.35 5959487.87 0.14 5959487.86 0.02 5959487.86 0.16 5959487.85 0.03 5959487.84 bl LU4`J.4b N /U 1 / 5~. /by VV '14`J b :i:i.167 612049.44 N 70 17 53.768 W 149 5 33.267 612049.44 N 70 17 53.768 W 149 5 33.267 612049.45 N 70 17 53.768 W 149 5 33.267 612049.46 N 70 17 53.767 W 149 5 33.267 612049.48 N 70 17 53.767 W 149 5 33.266 612049.49 N 70 17 53.767 W 149 5 33.266 612049.50 N 70 17 53.766 W 149 5 33.266 612049.50 N 70 17 53.766 W 149 5 33.266 612049.50 N 70 17 53.765 W 149 5 33.266 612049.51 N 70 17 53.765 W 149 5 33 6 612049.53 N 70 17 53.765 W 149 5 3~ 612049.55 N 70 17 53.764 W 149 5 33.264 612049.57 N 70 17 53.764 W 149 5 33.264 612049.58 N 70 17 53.763 W 149 5 33.264 612049.58 N 70 17 53.763 W 149 5 33.264 612049.59 N 70 17 53.762 W 149 5 33.263 612049.60 N 70 17 53.762 W 149 5 33.263 612049.63 N 70 17 53.761 W 149 5 33.262 612049.64 N 70 17 53.761 W 149 5 33.262 612049.66 N 70 17 53.761 W 149 5 33.261 612049.66 N 70 17 53.760 W 149 5 33.261 612049.67 N 70 17 53.760 W 149 5 33.261 612049.70 N 70 17 53.759 W 149 5 33.260 612049.72 N 70 17 53.759 W 149 5 33.260 612049.74 N 70 17 53.758 W 149 5 33.259 612049.76 N 70 17 53.758 W 149 5 33.259 612049.76 N 70 17 53.758 W 149 5 33.259 612049.76 N 70 17 53.757 W 149 5 612049.76 N 70 17 53.757 W 149 5 612049.76 N 70 17 53.757 W 149 5 33. 9 612049.77 N 70 17 53.756 W 149 5 33.258 612049.77 N 70 17 53.756 W 149 5 33.258 612049.76 N 70 17 53.756 W 149 5 33.259 612049.75 N 70 17 53.755 W 149 5 33.259 612049.75 N 70 17 53.755 W 149 5 33.259 612049.75 N 70 17 53.755 W 149 5 33.259 612049.74 N 70 17 53.755 W 149 5 33.259 612049.74 N 70 17 53.755 W 149 5 33.259 612049.74 N 70 17 53.755 W 149 5 33.259 612049.74 N 70 17 53.754 W 149 5 33.259 SurveyEditor Ver SP 1.0 Bld(doc40x_56) W-17\W-17\W-17A\W-17A Generated 9/26/2005 1:52 PM Page 2 of 9 ' Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Fasting Latitude Longitude - Depth Section Departure ft de de ft ft ft ft ft ft k de 1100 ft ftU5 ftUS yc3.vo u.uv iyc.34 o3a.au yc3.uo u./o 2.44 t.3Z -z.z3 U.t)/ U.11 5y094tf/.tfZ ti1[U49./3 N /U 1 / 53./54 W 149 5 33.260 937.46 0.05 178.24 852.90 937.46 0.75 2.46 2.34 -2.24 0.67 0.09 5959487.81 612049.73 N 70 17 53.754 W 149 5 33.260 951.86 0.05 173.85 867.30 951.86 0.75 2.47 2.35 -2.25 0.67 0.03 5959487.80 612049.73 N 70 17 53.754 W 149 5 33.260 966.06 0.05 191.64 881.50 966.06 0.75 2.48 2.36 -2.26 0.67 0.11 5959487.79 612049.73 N 70 17 53.754 W 149 5 33.260 980.26 0.08 203.56 895.70 980.26 0.75 2.50 2.37 -2.28 0.66 0.23 5959487.77 612049.73 N 70 17 53.754 W 149 5 33.260 994.46 0.10 197.71 909.90 994.46 0.74 2.52 2.39 -2.30 0.65 0.15 5959487.75 612049.72 N 70 17 53.754 W 149 5 33.260 1008.56 0.08 188.17 924.00 1008.56 0.73 2.54 2.41 -2.32 0.65 0.18 5959487.73 612049.71 N 70 17 53.753 W 149 5 33.260 1022.76 0.07 181.09 938.20 1022.76 0.73 2.56 2.43 -2.34 0.65 0.10 5959487.71 612049.71 N 70 17 53.753 W 149 5 33.260 1036.96 0.08 189.82 952.40 1036.96 0.73 2.58 2.44 -2.36 0.65 0.11 5959487.69 612049.71 N 70 17 53.753 W 149 5 33.260 1051.06 0.10 205.25 966.50 1051.06 0.73 2.60 2.46 -2.38 0.64 0.22 5959487.67 612049.70 N 70 17 53.753 W 149 5 33.260 1065.26 0.10 203.60 980.70 1065.26 0.72 2.63 2.48 -2.40 0.63 0.02 5959487.65 612049.69 N 70 17 53.753 W 149 5 33 1 1079.46 0.12 182.40 994.90 1079.46 0.71 2.65 2.51 -2.43 0.62 0.32 5959487.62. 612049.69 N 70 17 53.752 W 149 5 3~ 1093.66 0.13 154.98 1009.10 1093.66 0.72 2.68 2.54 -2.46 0.63 0.42 5959487.59 612049.70 N 70 17 53.752 W 149 5 33.261 1107.76 0.17 142.33 1023.20 1107.76 0.74 2.72 2.57 -2.49 0.65 0.37 5959487.56 612049.72 N 70 17 53.752 W 149 5 33.260 1121.96 0.23 136.13 1037.40 1121.96 0.77 2.77 2.62 -2.52 0.68 0.45 5959487.53 612049.75 N 70 17 53.751 W 149 5 33.259 1136.16 0.38 122.21 1051.60 1136.16 0.84 2.85 2.68 -2.57 0.74 1,17 5959487.48 612049.81 N 70 17 53.751 W 149 5 33.257 1150.36 0.65 110.47 1065.80 1150.36 0.95 2.97 2.76 -2.62 0.86 2.03 5959487.43 612049.93 N 70 17 53.750 W 149 5 33.254 1164.46 0.98 102.12 1079.89 1164.45 1.15 3.17 2.88 -2.68 1.05 2.48 5959487.38 612050.12 N 70 17 53.750 W 149 5 33.248 1178.76 1.38 97.21 1094.19 1178.75 1.44 3.47 3.04 -2.72 1.34 2.88 5959487.34 612050.41 N 70 17 53.749 W 149 5 33.240 1192.86 1.73 93.77 1108.29 1192.85 1.82 3.85 3.25 -2.76 1.72 2.57 5959487.31 612050.79 N 70 17 53.749 W 149 5 33.229 1207.06 2.00 91.88 1122.48 1207.04 2.28 4.31 3.54 -2.78 2.18 1.95 5959487.29 612051.25 N 70 17 53.749 W 149 5 33.215 1221.26 2.30 91.12 1136.67 1221.23 2.82 4.84 3.90 -2.80 2.71 2.12 5959487.29 612051.79 N 70 17 53.749 W 149 5 33.200 1235.46 2.58 90.53 1150.85 1235.41 3.42 5.45 4.35 -2.80 3.32 1.98 5959487.29 612052.39 N 70 17 53.749 W 149 5 33.182 1249.66 2.90 90.43 1165.04 1249.60 4.10 6.13 4.89 -2.81 4.00 2.25 5959487.29 612053.07 N 70 17 53.749 W 149 5 33.162 1263.86 3.27 90.33 1179.22 1263.78 4.86 6.89 5.53 -2.81 4.76 2.61 5959487.30 612053.83 N 70 17 53.749 W 149 5 33.140 1277.96 3.68 89.86 1193.29 1277.85 5.72 7.75 6.28 -2.82 5.62 2.91 5959487.31 612054.69 N 70 17 53.749 W 149 5 33.115 1292.16 4.12 89.03 1207.46 1292.02 6.68 8.71 7.16 -2.81 6.58 3.12 5959487.33 612055.65 N 70 17 53.749 W 149 5 33.087 1306.36 4.53 88.06 1221.62 1306.18 7.75 9.78 8.14 -2.78 7.65 2.93 5959487.38 612056.72 N 70 17 53.749 W 149 5 33.056 1320.46 4.97 87.54 1235.67 1320.23 8.91 10.95 9.23 -2.73 8.82 3.14 5959487.44 612057.89 N 70 17 53.749 W 149 5 1334.66 5.43 87.35 1249.81 1334.37 10.20 12.24 10.45 -2.68 10.11 3.24 5959487.51 612059.17 N 70 17 53.750 W 149 5 1348.86 5.90 86.98 1263.94 1348.50 11.59 13.64 11.80 -2.61 11.51 3.32 5959487.61 612060.57 N 70 17 53.751 W 149 5 32. 44 1363.06 6.43 86.68 1278.06 1362.62 13.11 15.16 13.27 -2.52 13.03 3.74 5959487.71 612062.09 N 70 17 53.751 W 149 5 32.899 1377.26 6.93 86.21 1292.16 1376.72 14.76 16.82 14.87 -2.42 14.68 3.54 5959487.84 612063.74 N 70 17 53.752 W 149 5 32.851 1391.36 7.43 85.49 1306.15 1390.71 16.51 18.58 16.59 -2.29 16.43 3.60 5959487.99 612065.49 N 70 17 53.754 W 149 5 32.800 1405.56 8.02 84.59 1320.22 1404.78 18.40 20.49 18.46 -2.13 18.34 4.24 5959488.19 612067.39 N 70 17 53.755 W 149 5 32.745 1419.76 8.63 83.57 1334.27 1418.83 20.44 22.54 20.47 -1.91 20.38 4.42 5959488.43 612069.43 N 70 17 53.757 W 149 5 32.685 1433.96 9.17 82.82 1348.30 1432.86 22.61 24.74 22.62 -1.65 22.56 3.89 5959488.72 612071.61 N 70 17 53.760 W 149 5 32.621 1448.26 9.60 82.21 1362.41 1446.97 24.91 27.07 24.91 -1.35 24.87 3.09 5959489.06 612073.92 N 70 17 53.763 W 149 5 32.554 1462.46 10.10 81.50 1376.40 1460.96 27.30 29.50 27.30 -1.00 27.28 3.62 5959489.44 612076.32 N 70 17 53.766 W 149 5 32.484 1476.66 10.63 80.89 1390.37 1474.93 29.81 32.06 29.81 -0.61 29.80 3.81 5959489.87 612078.84 N 70 17 53.770 W 149 5 32.410 1490.96 11.10 80.52 1404.41 1488.97 32.45 34.75 32.46 -0.18 32.46 3.32 5959490.35 612081.49 N 70 17 53.775 W 149 5 32.333 SurveyEditor Ver SP 1.0 Bld(doc40x_56) W-17\W-17\W-17A\W-17A Generated 9/26/2005 1:52 PM Page 3 of 9 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude - Depth Section Departure ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS 1505.16 11.53 80.19 1418.34 1502.90 35.18 37.54 35.21 0.29 35.21 3.06 5959490.85 612084.23 N 70 17 53.779 W 149 5 32.253 1519.36 12.05 80.05 1432.24 1516.80 38.01 40.44 38.08 0.79 38.07 3.67 5959491.40 612087.08 N 70 17 53.784 W 149 5 32.169 1533.66 12.63 80.13 1446.21 1530.77 41.00 43.49 41.10 1.31 41.08 4.06 5959491.97 612090.08 N 70 17 53.789 W 149 5 32.082 1547.96 13.25 80.19 1460.15 1544.71 44.14 46.70 44.27 1.86 44.23 4.34 5959492.56 612093.23 N 70 17 53.795 W 149 5 31.990 1573.16 14.20 80.10 1484.63 1569.19 49.98 52.68 50.21 2.88 50.12 3.77 5959493.67 612099.10 N 70 17 53.805 W 149 5 31.818 1603.06 15.05 80.00 1513.56 1598.12 57.37 60.23 57.71 4.19 57.56 2.84 5959495.09 612106.52 N 70 17 53.817 W 149 5 31.601 1635.56 15.87 79.91 1544.88 1629.44 65.84 68.89 66.34 5.70 66.09 2.52 5959496.72 612115.02 N 70 17 53.832 W 149 5 31.352 1672.46 16.88 79.94 1580.28 1664.84 76.00 79.29 76.70 7.52 76.33 2.74 5959498.70 612125.24 N 70 17 53.850 W 149 5 31.054 1709.96 17.82 80.49 1616.08 1700.64 86.95 90.47 87.86 9.42 87.35 2.54 5959500.76 612136.23 N 70 17 53.869 W 149 5 30.733 1747.56 18.40 81.39 1651.81 1736.37 98.41 102.16 99.53 11.26 98.89 1.71 5959502.77 612147.74 N 70 17 53.887 W 149 5 30.396 1785.36 18.78 82.51 1687.64 1772.20 110.27 114.21 111.58 12.94 110.83 1.38 5959504.63 612159.64 N 70 17 53.904 W 149 5 1823.36 19.28 83.90 1723.56 1808.12 122.51 126.60 123.97 14.41 123.13 1.78 5959506.28 612171.92 N 70 17 53.918 W 149 5 1861.36 19.97 85.19 1759.36 1843.92 135.17 139.36 136.73 15.62 135.83 2.14 5959507.68 612184.60 N 70 17 53.930 W 149 5 29.319 1899.46 20.72 86.10 1795.08 1879.64 148.33 152.61 149.96 16.62 149.04 2.14 5959508.88 612197.79 N 70 17 53.940 W 149 5 28.934 1937.66 21.28 86.63 1830.74 1915.30 161.95 166.30 163.64 17.49 162.70 1.55 5959509.95 612211.44 N 70 17 53.948 W 149 5 28.536 1975.86 21.90 86.86 1866.26 1950.82 175.94 180.35 177.68 18.29 176.74 1.64 5959510.96 612225.46 N 70 17 53.956 W 149 5 28.127 2014.16 22.75 87.06 1901.69 1986.25 190.43 194.90 192.21 19.06 191.26 2.23 5959511.95 612239.97 N 70 17 53.964 W 149 5 27.704 2052.46 23.68 87.33 1936.89 2021.45 205.47 210.00 207.29 19.80 206.34 2.44 5959512.91 612255.04 N 70 17 53.971 W 149 5 27.264 2090.86 24.52 87.52 1971.94 2056.50 221.10 225.68 222.95 20.50 222.01 2.20 5959513.85 612270.69 N 70 17 53.978 W 149 5 26.807 2129.16 25.35 87.49 2006.67 2091.23 237.20 241.83 239.08 21.20 238.14 2.17 5959514.79 612286.81 N 70 17 53.985 W 149 5 26.337 2167.66 26.30 87.31 2041.33 2125.89 253.91 258.60 255.84 21.97 254.89 2.48 5959515.80 612303.54 N 70 17 53.992 W 149 5 25.849 2205.96 27.37 87.19 2075.50 2160.06 271.14 275.89 273.11 22.80 272.16 2.80 5959516.89 612320.80 N 70 17 54.000 W 149 5 25.345 2244.36 28.48 87.07 2109.43 2193.99 289.05 293.87 291.09 23.70 290.12 2.89 5959518.06 612338.74 N 70 17 54.009 W 149 5 24.822 2282.76 29.65 87.08 2142.99 2227.55 307.64 312.52 309.73 24.65 308.75 3.05 5959519.29 612357.35 N 70 17 54.019 W 149 5 24.279 2321.06 30.80 87.20 2176.09 2260.65 326.84 331.80 329.01 25.61 328.01 3.01 5959520.53 612376.59 N 70 17 54.028 W 149 5 23.717 2359.36 31.85 87.39 2208.80 2293.36 346.68 351.72 348.91 26.55 347.90 2.75 5959521.77 612396.46 N 70 17 54.037 W 149 5 23.138 2397.26 32.78 87.60 2240.83 2325.39 366.88 371.98 369.16 27.43 368.14 2.47 5959522.96 612416.69 N 70 17 54.046 W 149 5 22.548 2434.86 33.58 87.88 2272.30 2356.86 387.40 392.55 389.72 28.24 388.70 2.17 5959524.07 612437.23 N 70 17 54.054 W 149 5 21.948 2472.56 34.37 88.20 2303.57 2388.13 408.41 413.62 410.78 28.96 409.76 2.15 5959525.11 612458.27 N 70 17 54.061 W 149 5 2510.26 35.28 88.39 2334.51 2419.07 429.89 435.15 432.29 29.60 431.27 2.43 5959526.07 612479.78 N 70 17 54.067 W 149 5 2547.96 36.37 88.51 2365.08 2449.64 451.91 457.22 454.34 30.20 453.33 2.90 5959526.99 612501.82 N 70 17 54.073 W 149 5 20.064 2585.66 37.33 88.63 2395.25 2479.81 474.48 479.83 476.93 30.77 475.93 2.55 5959527.89 612524.41 N 70 17 54.079 W 149 5 19.405 2623.26 38.02 88.82 2425.01 2509.57 497.42 502.81 499.89 31.28 498.91 1.86 5959528.75 612547.37 N 70 17 54.084 W 149 5 18.736 2660.96 38.57 88.96 2454.60 2539.16 520.75 526.17 523.23 31.73 522.27 1.48 5959529.55 612570.72 N 70 17 54.088 W 149 5 18.055 2698.56 39.13 88.86 2483.88 2568.44 544.29 549.75 546.80 32.18 545.85 1.50 5959530.35 612594.29 N 70 17 54.093 W 149 5 17.367 2736.26 39.78 88.23 2512.99 2597.55 568.21 573.71 570.74 32.79 569.80 2.02 5959531.32 612618.23 N 70 17 54.099 W 149 5 16.669 2773.86 40.40 86.89 2541.75 2626.31 592.34 597.92 594.95 33.82 593.99 2.83 5959532.71 612642.40 N 70 17 54.109 W 149 5 15.964 2811.46 40.85 85.30 2570.29 2654.85 616.69 622.41 619.43 35.49 618.41 3.00 5959534.74 612666.79 N 70 17 54.125 W 149 5 15.252 2849.16 41.13 84.05 2598.75 2683.31 641.21 647.13 644.14 37.78 643.03 2.30 5959537.40 612691.37 N 70 17 54.148 W 149 5 14.534 2886.56 41.40 83.53 2626.86 2711.42 665.61 671.80 668.78 40.45 667.55 1.17 5959540.44 612715.85 N 70 17 54.174 W 149 5 13.819 SurveyEditor Ver SP 1.0 Bld(doc4Ox_56) W-17\W-17\W-17A\W-17A Generated 9!26!2005 1:52 PM Page 4 of 9 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude ' Depth Section Departure ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS caL4.ub 2961.56 2999.26 3036.86 3074.26 3111.26 3148.16 3185.16 3222.06 3259.06 3296.06 3333.06 3370.06 3406.96 3443.96 3481.06 3517.96 3554.96 3591.96 3629.06 41.bL 41.40 41.15 40.98 40.88 40.70 40.65 40.62 40.48 40.47 40.40 40.27 40.25 40.17 39.93 39.80 39.80 39.75 39.58 39.43 8.5.4`J Lbb4. `Jb L/3y .bL byV. ~lb b`Jb. b3 6y3 .5/ 43. Zb 83,48 2683. 07 2767 .63 714. 71 721. 46 718 .37 46. 08 83.49 2711. 40 2795 .96 739. 30 746. 33 743 .21 48. 90 83.50 2739. 75 2824 .31 763. 72 771. 03 767 .88 51. 70 83.49 2768. 01 2852 .57 787. 95 795. 53 792 .36 54. 47 83.47 83.45 83.44 83.42 83.41 83.47 83.53 83.57 83.66 83.74 83.79 83.82 83.81 83.80 83.80 2796.02 2824.01 2852.08 2880.12 2908.27 2936.43 2964.63 2992.87 3021.05 3049.37 3077.85 3106.20 3134.63 3163.12 3191.74 3666. 06 39. 25 83 .82 3220. 36 3702. 86 39. 03 83 .84 3248. 90 3739. 86 39. 02 83 .90 3277. 64 3776. 26 39. 02 84 .01 3305. 92 3812. 56 39. 05 84 .13 3334. 12 3848.76 3884.96 3921.26 3957.56 3993.86 4030.26 4066.66 4102.86 4139.26 4175.56 4211.86 4248.16 4284.36 4320.66 4356.96 4393.16 2880.58 2908.57 2936.64 2964.68 2992.83 3020.99 3049.19 3077.43 3105.61 3133.93 3162.41 3190.76 3219.19 3247.68 3276.30 3304.92 3333.46 3362.20 3390.48 3418.68 3446.78 3474.86 3502.99 3531.12 3559.22 3587.34 3615.43 3643.34 3671.39 3699.39 3727.40 3755.39 3783.28 3811.19 3839.09 3866.92 811.84 835.62 859.44 883.16 906.90 930.62 954.30 977.94 1001.50 1025.06 1048.58 1071.96 1095.38 1118.75 1142.10 1165.31 1188.30 1211.36 1234.04 1256.68 1279.28 1301.92 1324.65 1347.40 1370.17 byZ.ZZ U.33 5y59543.61 61174U.4/ N /U 17 54.201 W 149 5 13.100 716.89 0.32 5959546.79 612765.09 N 70 17 54.229 W 149 5 12.381 741.60 0.66 5959549.98 612789.75 N 70 17 54.257 W 149 5 11.661 766.14 0.45 5959553.15 612814.25 N 70 17 54.284 W 149 5 10.945 790.49 0.27 5959556.29 612838.55 N 70 17 54.312 W 149 5 10.236 814.50 0.49 5959559.39 612862.52 N 70 17 54.339 W 149 5 9.536 838.40 0.14 5959562.48 612886.37 N 70 17 54.365 W 149 5 8.839 862.33 0.08 5959565.59 612910.26 N 70 17 54.392 W 149 5 8.141 886.17 0.38 5959568.69 612934.04 N 70 17 54.419 W 149 5 7.447 910.02 0.03 5959571.80 612957.86 N 70 17 54.447 W 149 5 6.751 933.87 0.22 5959574.90 612981.65 N 70 17 54.473 W 149 5 6 957.66 0.37 5959577.96 613005.40 N 70 17 54.500 W 149 5 981.42 0.09 5959581.00 613029.12 N 70 17 54.526 W 149 5 1005.09 0.27 5959584.00 613052.75 N 70 17 54.553 W 149 5 3.980 1028.76 0.66 5959586.97 613076.37 N 70 17 54.578 W 149 5 3.290 1052.40 0.36 5959589.90 613099.96 N 70 17 54.604 W 149 5 2.601 1075.88 0.05 5959592.80 613123.40 N 70 17 54.629 W 149 5 1.916 1099.41 0.14 5959595.70 613146.89 N 70 17 54.654 W 149 5 1.230 1122.89 0.46 5959598.60 613170.33 N 70 17 54.679 W 149 5 0.546 1146.36 0.40 5959601.50 613193.75 N 70 17 54.704 W 149 4 59.862 1169.67 0.49 5959604.37 613217.03 N 70 17 54.729 W 149 4 59.182 1192.77 0.60 5959607.21 613240.08 N 70 17 54.753 W 149 4 58.509 1215.93 0.11 5959610.05 613263.20 N 70 17 54.777 W 149 4 57.834 1238.72 0.19 5959612.80 613285.95 N 70 17 54.801 W 149 4 57.169 1261.46 0.22 5959615.50 613308.65 N 70 17 54.824 W 149 4 56.506 1284.16 0.22 5959618.15 613331.31 N 70 17 54.847 W 149 4 55.845 1306.90 0.32 5959620.76 613354.01 N 70 17 54.869 W 149 4 55.182 1329.73 0.24 5959623.33 613376.81 N 70 17 54.891 W 149 4 54.516 1352.57 0.07 5959625.88 613399.61 N 70 17 54.913 W 149 4 53.850 1375.45 0.42 5959628.43 613422.45 N 70 17 54.935 W 149 4 1398.45 0.36 5959631.02 613445.41 N 70 17 54.957 W 149 4 52.513 1421.49 0.27 5959633.65 613468.41 N 70 17 54.979 W 149 4 51.841 1444.42 0.14 5959636.30 613491.31 N 70 17 55.002 W 149 4 51.173 1467.50 0.14 5959638.94 613514.35 N 70 17 55.024 W 149 4 50.500 1490.49 0.29 5959641.55 613537.30 N 70 17 55.047 W 149 4 49.830 1513.48 0.16 5959644.14 613560.24 N 70 17 55.069 W 149 4 49.160 1536.48 0.15 5959646.70 613583.21 N 70 17 55.090 W 149 4 48.489 1559.46 0.28 5959649.25 613606.15 N 70 17 55.112 W 149 4 47.819 1582.56 0.38 5959651.79 613629.21 N 70 17 55.134 W 149 4 47.146 1605.69 0.25 5959654.29 613652.31 N 70 17 55.155 W 149 4 46.472 819.70 816.51 57.22 843.75 840.54 59.96 867.85 864.61 62.71 891.84 888.58 65.45 915.85 912.58 68.21 939.85 963.80 987.71 1011.53 1035.34 1059.12 1082.74 1106.41 1130.03 1153.63 1177.09 1200.31 1223.61 1246.53 1269.39 1292.21 1315.06 1338.00 1360.95 1383.93 936.56 960.49 984.38 1008.19 1031.99 1055.76 1079.37 1103.03 1126.64 1150.24 1173.68 1196.90 1220.20 1243.11 1265.96 1288.78 1311.63 1334.57 1357.51 1380.49 70.95 73.66 76.34 78.99 81.61 84.19 86.74 89.29 91.84 94.39 96.91 99.41 101.90 104.31 106.67 108.99 111.26 113.49 115.69 117.90 120.15 122.44 124.75 127.05 129.32 1393.08 1407.04 1403.60 1416.01 1430.19 1426.75 1438.85 1453.24 1449.80 1461.83 1476.44 1472.99 1484.72 1499.54 1496.09 1507.61 1522.63 1519.18 1530.51 1545.74 1542.29 1553.39 1568.83 1565.38 1576.40 1592.03 1588.58 1599.43 1615.26 1611.81 1622.39 1638.41 1634.96 131.56 133.78 135.99 138.18 140.33 142.43 1628.74 0.27 5959656.72 613675.33 N 70 17 55.175 W 149 4 45.800 SurveyEditor Ver SP 1.0 Bld( doc40x_56) W-17\W-17\W-17A\W-17A Generated 9/26/2005 1:52 PM Page 5 of 9 39.10 39.18 39.22 39.20 39.35 39.47 39.53 39.58 39.58 39.48 39.52 39.57 39.67 39.80 39.78 39.72 84.23 84.36 84.48 84.50 84.46 84.38 84.26 84.26 84.34 84.40 84.47 84.50 84.53 84.61 84.75 84.87 3362.22 3390.30 3418.43 3446.56 3474.66 3502.78 3530.87 3558.78 3586.83 3614.83 3642.84 3670.83 3698.72 3726.63 3754.53 3782.36 Comments Measured Inclination Azimuth Sub~Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft' ft ft ft ft ft de 1100 ft ftUS ftUS wwc~.io oy.rc ow.yc obiu.uo ooaw.bi 104b.L4 100L4G lbb/.`Jb -144.413 lbb~l.bb U.Uy bybyb5y.l7 b"136yiS.ZU N /U ~~ bb.lyb W 14y445.131 4464.76 39.77 85.06 3837.42 3921.98 1667.80 1684.18 1680.73 146.46 1674.33 0.29 5959661.44 613720.84 N 70 17 55.215 W 149 4 44.471 4500.26 39.78 85.24 3864.70 3949.26 1690.35 1706.89 1703.44 148.38 1696.96 0.33 5959663.69 613743.44 N 70 17 55.234 W 149 4 43.811 4535.86 39.70 85.37 3892.08 3976.64 1712.95 1729.65 1726.20 150.25 1719.64 0.32 5959665.89 613766.09 N 70 17 55.252 W 149 4 43.150 4571.46 39.63 85.45 3919.48 4004.04 1735.52 1752.37 1748.92 152.07 1742.30 0.24 5959668.05 613788.71 N 70 17 55.270 W 149 4 42.489 4607.06 39.55 85.50 3946.92 4031.48 1758.05 1775.06 1771.61 153.86 1764.91 0.24 5959670.18 613811.30 N 70 17 55.287 W 149 4 41.830 4642.56 39.57 85.48 3974.29 4058.85 1780.51 1797.67 1794.21 155.63 1787.45 0.07 5959672.29 613833.81 N 70 17 55.305 W 149 4 41.173 4678.16 39.78 85.40 4001.69 4086.25 1803.08 1820.40 1816.94 157.44 1810.11 0.61 5959674.44 613856.43 N 70 17 55.323 W 149 4 40.512 4713.76 39.93 85.43 4029.02 4113.58 1825.74 1843.21 1839.76 159.26 1832.85 0.42 5959676.60 613879.14 N 70 17 55.340 W 149 4 39.849 4749.36 40.15 85.52 4056.27 4140.83 1848.49 1866.11 1862.66 161.07 1855.68 0.64 5959678.74 613901.94 N 70 17 55.358 W 149 4 39.184 4784.76 40.47 85.65 4083.27 4167.83 1871.24 1889.01 1885.56 162.83 1878.51 0.93 5959680.85 613924.74 N 70 17 55.375 W 149 4 3 8 4820.36 40.73 85.84 4110.30 4194.86 1894.27 1912.18 1908.72 164.55 1901.62 0.81 5959682.91 613947.82 N 70 17 55.392 W 149 4 4855.86 41.02 85.97 4137.14 4221.70 1917.36 1935.41 1931.95 166.21 1924.79 0.85 5959684.91 613970.96 N 70 17 55.409 W 149 4 3 4891.46 41.25 86.08 4163.95 4248.51 1940.65 1958.83 1955.37 167.83 1948.15 0.68 5959686.89 613994.29 N 70 17 55.424 W 149 4 36.488 4926.96 41.47 86.27 4190.60 4275.16 1963.98 1982.29 1978.82 169.40 1971.56 0.71 5959688.80 614017.67 N 70 17 55.440 W 149 4 35.806 4962.36 41.70 86.45 4217.08 4301.64 1987.36 2005.79 2002.31 170.89 1995.01 0.73 5959690.64 614041.09 N 70 17 55.454 W 149 4 35.122 4997.76 41.93 86.51 4243.46 4328.02 2010.85 2029.39 2025.91 172.34 2018.56 0.66 5959692.44 614064.62 N 70 17 55.469 W 149 4 34.436 5033.16 42.13 86.56 4269.75 4354.31 2034.44 2053.09 2049.60 173.77 2042.22 0.57 5959694.22 614088.25 N 70 17 55.483 W 149 4 33.746 5068.46 42.35 86.68 4295.89 4380.45 2058.06 2076.82 2073.32 175.17 2065.91 0.66 5959695.98 614111.92 N 70 17 55.496 W 149 4 33.055 5103.16 42.62 86.79 4321.48 4406.04 2081.39 2100.26 2096.75 176.51 2089.31 0.81 5959697.66 614135.29 N 70 17 55.509 W 149 4 32.373 5137.86 42.85 86.82 4346.96 4431.52 2104.84 2123.80 2120.29 177.82 2112.82 0.67 5959699.32 614158.78 N 70 17 55.522 W 149 4 31.688 5172.46 43.10 86.82 4372.28 4456.84 2128.33 2147.39 2143.87 179.13 2136.37 0.72 5959700.98 614182.30 N 70 17 55.535 W 149 4 31.001 Tie-In Survey GCT MS 5207.26 43.50 86.93 4397.61 4482.17 2152.09 2171.26 2167.72 180.43 2160.20 1.17 5959702.64 614206.11 N 70 17 55.548 W 149 4 30.307 Blind (Inc Only) 5333.86 38.31 87.44 4493.26 4577.82 2234.65 2254.13 2250.55 184.52 2242.97 4.11 5959707.96 614288.80 N 70 17 55.588 W 149 4 27.894 Blind (Inc Only) 5429.59 37.71 87.87 4568.68 4653.24 2293.43 2313.08 2309.45 186.93 2301.87 0.69 5959711.25 614347.65 N 70 17 55.611 W 149 4 26.177 First MWD+IFR+MS 5525.24 37.08 88.34 4644.67 4729.23 2351.37 2371.16 2367.47 188.85 2359.93 0.72 5959714.04 614405.67 N 70 17 55.630 W 149 4 24.484 5621.26 32.13 90.03 4723.68 4808.24 2405.81 2425.68 2421.87 189.68 2414.43 5.25 5959715.68 614460.15 N 70 17 55.638 W 149 4 22.896 5716.20 29.79 89.68 4805.09 4889.65 2454.61 2474.51 2470.57 189.80 2463.27 2.47 5959716.52 614508.98 N 70 17 55.639 W 149 4 21.472 5812.13 25.51 91,56 4890.05 4974.61 2499.09 2519.02 2514.91 189.37 2507.77 4.55 5959716.76 614553.47 N 70 17 55.635 W 149 4 20.175 5906.98 20.81 95.84 4977.24 5061.80 2536.35 2556.30 2551.84 187.10 2544.97 5.26 5959715.04 614590.70 N 70 17 55.612 W 149 4 6002.21 20.80 99.24 5066.26 5150.82 2570.01 2590.11 2584.95 182.66 2578.49 1.27 5959711.11 614624.28 N 70 17 55.568 W 149 4 18. 13 6098.30 20.68 99.23 5156.12 5240.68 2603.78 2624.14 2618.08 177.20 2612.07 0.12 5959706.15 614657.94 N 70 17 55.515 W 149 4 17.134 6194.19 20.31 95.77 5245.95 5330.51 2637.19 2657.71 2650.98 172.81 2645.35 1.32 5959702.25 614691.27 N 70 17 55.471 W 149 4 16.164 6290.01 19.94 95.67 5335.92 5420.48 2670.09 2690.67 2683.51 169.52 2678.15 0.39 5959699.46 614724.12 N 70 17 55.439 W 149 4 15.208 6385.54 19.59 95.26 5425.82 5510.38 2702.34 2722.98 2715.41 166.45 2710.31 0.39 5959696.86 614756.32 N 70 17 55.408 W 149 4 14.271 6480.71 19.56 95.96 5515.49 5600.05 2734.17 2754.86 2746.90 163.33 2742.04 0.25 5959694.22 614788.09 N 70 17 55.378 W 149 4 13.346 6576.74 18.71 96.11 5606.21 5690.77 2765.57 2786.34 2777.96 160.02 2773.34 0.89 5959691.38 614819.44 N 70 17 55.345 W 149 4 12.433 6672.67 20.01 92.89 5696.72 5781.28 2797.33 2818.13 2809.46 157.56 2805.04 1.75 5959689.38 614851.16 N 70 17 55.321 W 149 4 11.509 6769.18 19.50. 93.82 5787.55 5872.11 2829.94 2850.75 2841.87 155.65 2837.60 0.62 5959687.96 614883.74 N 70 17 55.302 W 149 4 10.560 6865.72 18.97 93.67 5878.70 5963.26 2861.74 2882.56 2873.44 153.57 2869.34 0.55 5959686.36 614915.51 N 70 17 55.281 W 149 4 9.635 6973.16 19.83 93.43 5980.04 6064.60 2897.41 2918.25 2908.90 151.36 2904.95 0.80 5959684.68 614951.15 N 70 17 55.259 W 149 4 8.597 SurveyEditor Ver SP 1.0 Bld( doc40x_56) W-17\W-17\W-17A\W-17A Generated 9/26/2005 1:52 PM Page 6 of 9 Comments Measured Inclination Azimuth Sub•Sea ND 7yp Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude - Depth Section Departure ft de de ft ft ft ft ft ft ft de 1700 ft ftUS ftUS +wo.yv io.vv yo.or ovrv.u+ o+oY.a+ caco.oc ta4y.oo ty4v. ~+ -14y.~V [`J3o.31 l.[3 ~y0yUt5S.Zy tl"14`J7SY.b3 N /U 1 / 55.241 VV 14y 4 l.6t33 7164.08 18.51 91.75 6160.64 6245.20 2959.29 2980.13 2970.45 148.14 2966.75 0.56 5959682.38 615012.98 N 70 17 55.227 W 149 4 6.795 7259.60 19.23 91.02 6251.03 6335.59 2990.18 3011.02 3001.26 147.39 2997.64 0.79 5959682.10 615043.87 N 70 17 55.220 W 149 4 5.895 7354.57 20.54 91.11 6340.34 6424.90 3022.47 3043.32 3033.49 146.79 3029.93 1.38 5959681.98 615076.17 N 70 17 55.214 W 149 4 4.953 7450.17 20.98 93.68 6429.73 6514.29 3056.35 3077.21 3067.23 145.37 3063.78 1.06 5959681.06 615110.03 N 70 17 55.200 W 149 4 3.967 7545.73 19.10 92.71 6519.50 6604.06 3089.09 3109.95 3099.80 143.53 3096.47 2.00 5959679.71 615142.75 N 70 17 55.182 W 149 4 3.014 7641.29 19.48 94.48 6609.70 6694.26 3120.64 3141.52 3131.18 141.55 3127.97 0.73 5959678.19 615174.27 N 70 17 55.162 W 149 4 2.095 7736.44 21.14 96.20 6698.93 6783.49 3153.61 3174.54 3163.88 138.46 3160.85 1.85 5959675.59 615207.19 N 70 17 55.131 W 149 4 1.137 7831.90 20.36 96.88 6788.20 6872.76 3187.33 3208.36 3197.29 134.61 3194.45 0.86 5959672.25 615240.84 N 70 17 55.093 W 149 4 0.158 7927.87 18.84 96.81 6878.60 6963.16 3219.41 3240.55 3229.06 130.77 3226.41 1.58 5959668.89 615272.85 N 70 17 55.056 W 149 3 59.226 8023.03 22.09 95.18 6967.75 7052.31 3252.60 3273.82 3261.99 127.33 3259.50 3.47 5959665.94 615305.98 N 70 17 55.022 W 149 3 5 8118.83 25.35 93.50 7055.44 7140.00 3291.10 3312.35 3300.27 124.45 3297.92 3.47 5959663.64 615344.44 N 70 17 54.993 W 149 3 8211.83 29.87 91.58 7137.83 7222.39 3334.19 3355.43 3343.21 122.60 3340.96 4.95 5959662.42 615387.50 N 70 17 54.975 W 149 3 8308.73 33.89 92.43 7220.10 7304.66 3385.35 3406.60 3394.25 120.79 3392.10 4.17 5959661.37 615438.65 N 70 17 54.957 W 149 3 54.396 8400.98 38.72 94.64 7294.42 7378.98 3439.93 3461.20 3448.58 117.36 3446.59 5.42 5959658.76 615493.18 N 70 17 54.923 W 149 3 52.808 8499.18 42.18 95.82 7369.14 7453.70 3503.53 3524.90 3511.79 111.53 3510.02 3.61 5959653.88 615556.69 N 70 17 54.865 W 149 3 50.959 8595.29 42.67 95.47 7440.08 7524.64 3568.25 3589.73 3576.09 105.15 3574.54 0.57 5959648.46 615621.29 N 70 17 54.802 W 149 3 49.078 8691.51 42.24 95.99 7511.08 7595.64 3633.07 3654.68 3640.50 98.67 3639.17 0.58 5959642.95 615686.00 N 70 17 54.738 W 149 3 47.194 8787.21 41.92 96.73 7582.10 7666.66 3697.02 3718.82 3704.04 91.57 3702.90 0.62 5959636.79 615749.83 N 70 17 54.668 W 149 3 45.336 8882.52 43.28 96.27 7652.26 7736.82 3761.34 3783.33 3767.94 84.27 3767.00 1.46 5959630.45 615814.03 N 70 17 54.596 W 149 3 43.468 8978.36 42.80 96.67 7722.31 7806.87 3826.57 3848.74 3832.77 76.90 3832.00 0.58 5959624.05 615879.12 N 70 17 54.523 W 149 3 41.573 9074.12 42.38 96.95 7792.81 7877.37 3891.15 3913.55 3896.96 69.21 3896.34 0.48 5959617.33 615943.57 N 70 17 54.447 W 149 3 39.698 9169.88 41.40 97.17 7864.09 7948.65 3954.85 3977.48 3960.27 61.36 3959.80 1.03 5959610.42 616007.13 N 70 17 54.369 W 149 3 37.848 9265.49 42.48 97.53 7935.21 8019.77 4018.49 4041.38 4023.52 53.18 4023.17 1.16 5959603.19 616070.61 N 70 17 54.289 W 149 3 36.001 9361.38 43.49 97.01 8005.36 8089.92 4083.60 4106.76 4088.27 44.91 4088.02 1.12 5959595.89 616135.57 N 70 17 54.207 W 149 3 34.111 9456.06 42.62 97.71 8074.54 8159.10 4147.96 4171.40 4152.29 36.63 4152.13 1.05 5959588.57 616199.79 N 70 17 54.125 W 149 3 32.242 9551.36 43.00 96.58 8144.45 8229.01 4212.48 4236.16 4216.48 28.58 .4216.39 0.90 5959581.47 616264.15 N 70 17 54.046 W 149 3 30.369 9647.61 42.92 96.60 8214.89 8299.45 4277.87 4301.75 4281.60 21.05 4281.55 0.08 5959574.92 616329.41 N 70 17 53.971 W 149 3 28.470 9744.28 43.19 96.37 8285.53 8370.09 4343.67 4367.75 4347.14 13.60 4347.12 0.32 5959568.45 616395.08 N 70 17 53.898 W 149 3 8 9838.66 43.46 94.12 8354.19 8438.75 4408.33 4432.50 4411.61 7.68 4411.60 1.66 5959563.49 616459.64 N 70 17 53.839 W 149 3 9934.83 41.87 95.53 8424.91 8509.47 4473.42 4497.67 4476.54 2.21 4476.54 1.93 5959558.99 616524.65 N 70 17 53.785 W 149 3 2 6 10029.71 41.61 94.15 8495.71 8580.27 4536.51 4560.84 4539.48- -3.12 4539.48 1.01 5959554.60 616587.65 N 70 17 53.732 W 149 3 20.951 10125.81 42.49 92.95 8567.07 8651.63 4600.86 4625.20 4603.72 -7.10 4603.72 1.24 5959551.58 616651.94 N 70 17 53.693 W 149 3 19.079 10221.16 43.46 94.99 8636.83 8721.39 4665.81 4690.20 4668.56 -11.61 4668.55 1.78 5959548.04 616716.82 N 70 17 53.648 W 149 3 17.189 10267.99 46.24 94.62 8670.03 8754.59 4698.80 4723.22 4701.48 -14.37 4701.46 5.96 5959545.76 616749.77 N 7017 53.620 W 149 3 16.230 10339.62 45.82 94.33 8719.76 8804.32 4750.31 4774.77 4752.89 -18.39 4752.85 -0.65 5959542.51 616801.21 N 70 17 53.581 W 149 3 14.732 10371.23 47.98 95.29 8741.36 8825.92 4773.36 4797.85 4775.89 -20.33 4775.85 7.18 5959540.91 616824.23 N 70 17 53.561 W 149 3 14.061 10403.87 50.26 98.05 8762.72 8847.28 4797.95 4822.53 4800.41 -23.21 4800.35 9.47 5959538.40 616848.78 N 70 17 53.533 W 149 3 13.347 10435.02 52.51 99.75 8782.16 8866.72 4822.12 4846.86 4824.47 -26.98 4824.40 8.39 5959534.99 616872.87 N 70 17 53.496 W 149 3 12.646 10467.25 55.33 101.73 8801.14 8885.70 4847.87 4872.91 4850.09 -31.84 4849.98 10.06 5959530.51 616898.52 N 70 17 53.448 W 149 3 11.900 10497.93 57.50 102.14 8818.11 8902.67 4873.05 4898.46 4875.13 -37.13 4874.99 7.16 5959525.60 616923.60 N 70 17 53.396 W 149 3 11.172 SurveyEditor Ver SP 1.0 Bld( doc40x_56) W-17\W-17\W-17A\W-17A Generated 9/26/2005 1:52 PM Page 7 of 9 Measured Vertical Along Hole Comments Depth Inclination Azimuth Sub•Sea ND ND Section Departure Closure NS EW DLS Northing Easting Latitude Longitude - ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS iU533.1 I 5y.yri 1U4.4'1 2325J6.4U 259ZU.96 49UL.59 49LS.59 49U4.5U -44.U5 49U4.3U tf.94 5959519.11 616953.01 N 70 17 53.327 W 149 3 10.317 10562.65 61.43 104.61 8850.82 8935.38 4927.70 4954.29 4929.45 -50.49 4929.19 4.95 5959513.05 616977.99 N 70 17 53.264 W 149 3 9.592 10597.04 60.33 104.91 8867.56 8952.12 4957.02 4984.34 4958.58 -58.15 4958.24 3.29 5959505.83 617007.15 N 70 17 53.188 W 149 3 8.745 10629.33 60.32 105.59 8883.54 8968.10 4984.34 5012.39 4985.74 -65.53 4985.31 1.83 5959498.85 617034.32 N 70 17 53.116 W 149 3 7.956 10657.70 62.20 106.42 8897.19 8981.75 5008.48 5037.27 5009.74 -72.39 5009.21 7.11 5959492.35 617058.33 N 70 17 53.048 W 149 3 7.260 10692.36 64.80 107.07 8912.65 8997.21 5038.49 5068.28 5039.57 -81.32 5038.91 7.69 5959483.86 617088.15 N 70 17 52.960 W 149 3 6.394 10724.74 66.50 107.36 8926.00 9010.56 5066.97 5097.78 5067.89 -90.05 5067.09 5.31 5959475.55 617116.46 N 70 17 52.874 W 149 3 5.573 10754.11 68.91 109.28 8937.14 9021.70 5093.06 5124.95 5093.84 -98.60 5092.88 10.19 5959467.39 617142.37 N 70 17 52.790 W 149 3 4.821 10787.61 72.25 109.24 8948.28 9032.84 5123.25 5156.54 5123.86 -109.02 5122.70 9.97 5959457.42 617172.34 N 70 17 52.687 W 149 3 3.952 10819.60 74.58 109.70 8957.41 9041.97 5152.51 5187.20 5152.99 -119.24 5151.61 7.41 5959447.63 617201.39 N 70 17 52.586 W 149 3 3.110 10848.38 76.81 110.86 8964.52 9049.08 5179.00 5215.08 5179.37 -128.90 5177.76 8.68 5959438.36 617227.69 N 70 17 52.491 W 149 3 2.347 10880.49 79.69 111.09 8971.06 9055.62 5208.75 5246.52 5209.00 -140.16 5207.12 9.00 5959427.54 617257.20 N 70 17 52.380 W 149 3~ 10915.53 82.50 111.42 8976.48 9061.04 5241.44 5281.13 5241.60 -152.70 5239.37 8.07 5959415.48 617289.64 N 70 17 52.256 W 149 3 0.552 10943.50 84.43 110.61 8979.67 9064.23 5267.73 5308.92 5267.83 -162.67 5265.31 7.48 5959405.90 617315.72 N 70 17 52.158 W 149 2 59.796 10978.23 87.15 109.98 8982.21 9066.77 5300.64 5343.55 5300.68 -174.68 5297.80 8.04 5959394.38 617348.38 N 70 17 52.040 W 149 2 58.849 11011.37 90.03 109.06 8983.03 9067.59 5332.24 5376.68 5332.26 -185.75 5329.02 9.12 5959383.78 617379.76 N 70 17 51.931 W 149 2 57.940 11039.57 92.02 108.46 8982.53 9067.09 5359.26 5404.87 5359.26 -194.82 5355.71 7.37 5959375.11 617406.58 N 70 17 51.841 W 149 2 57.162 11074.49 95.25 106.79 8980.31 9064.87 5392.83 5439.72 5392.53 -205.37 5388.92 10.41 5959365.05 617439.94 N 70 17 51.737 W 149 2 56.194 11106.39 97.50 106.36 8976.77 9061.33 5423.53 5471.42 5423.55 -214.41 5419.31 7.18 5959356.47 617470.45 N 70 17 51.648 W 149 2 55.308 11134.74 100.00 105.25 8972.46 9057.02 5450.75 5499.44 5450.79 -222.04 5446.26 9.63 5959349.24 617497.52 N 70 17 51.573 W 149 2 54.523 11166.96 101.91 105.13 8966.34 9050.90 5481.56 5531.07 5481.63 -230.33 5476.79 5.94 5959341.41 617528.17 N 70 17 51.491 W 149 2 53.633 11199.33 102.17 105.03 8959.58 9044.14 5512.41 5562.73 5512.52 -238.57 5507.36 0.86 5959333.63 617558.85 N 70 17 51.410 W 149 2 52.742 11231.42 101.71 105.13 8952.94 9037.50 5543.00 5594.12 5543.17 -246.74 5537.67 1.47 5959325.91 617589.28 N 70 17 51.330 W 149 2 51.859 11262.59 101.95 105.06 8946.55 9031.11 5572.73 5624.63 5572.95 -254.68 5567.13 0.80 5959318.41 617618.85 N 70 17 51.251 W 149 2 51.000 11295.05 101.67 106.25 8939.91 9024.47 5603.62 5656.40 5603.91 -263.25 5597.72. 3.69 5959310.29 617649.56 N 70 17 51.167 W 149 2 50.109 11327.34 101.32 106.45 8933.48 9p18.04 5634.29 5688.04 5634.66 -272.16 5628.08 1.24 5959301.84 617680.05 N 70 17 51.079 W 149 2 49.224 11358.53 100.80 106.30 8927.49 9012.05 5663.96 5718.66 5664.42 -280.79 5657.45 1.73 5959293.65 617709.54 N 70 17 50.994 W 149 2 48.368 11390.60 100.73 106.50 8921.50 9006.06 5694.49 5750.16 5695.05 -289.69 5687.68 0.65 5959285.21 617739.89 N 70 17 50.906 W 149 2 47.487 11422.64 101.78 105.06 8915.25 8999.81 5725.02 5781.58 5725.69 -298.23 5717.91 5.49 5959277.11 617770.25 N 70 17 50.822 W 149 2 6 11453.57 101.64 104.12 8908.97 8993.53 5754.59 5811.87 5755.36 -305.86 5747.22 3.01 5959269.92 617799.67 N 70 17 50.747 W 149 2 11486.33 101.49 104.53 8902.40 8986.96 5785.96 5843.97 5786.84 -313.80 5778.32 1.31 5959262.45 617830.88 N 70 17 50.668 W 149 2 5 11518.65 101.15 104.68 8896.06 8980.62 5816.90 5875.66 5817.89 -321.79 5808.99 1.15 5959254.91 617861.66 N 70 17 50.589 W 149 2 43.952 11549.83 100.90 105.18 8890.10 8974.66 5846.74 5906.26 5847.86 -329.68 5838.56 1.77 5959247.47 617891.34 N 70 17 50.512 W 149 2 43.090 11581.98 100.56 104.97 8884.11 8968.67 5877.52 5937.85 5878.78 -337.89 5869.06 1.24 5959239.71 617921.96 N 70 17 50.431 W 149 2 42.201 11614.19 99.89 105.39 8878.39 :8962.95 5908.40 5969.55 5909.80 -346.19 5899.65 2.44 5959231.87 617952.67 N 70 17 50.349 W 149 2 41.309 11645.92 99.79 106.26 8872.97 8957.53 5938.77 6000.81 5940.33 -354.72 5929.73 2.72 5959223.79 617982.87 N 70 17 50.265 W 149 2 40.433 11677.63 99.89 105.49 8867.55 8952.11 5969.12 6032.05 5970.84 -363.27 5959.78 2.41 5959215.70 618013.04 N 70 17 50.180 W 149 2 39.557 11709.80 99.23 105.73 8862.21 8946.77 5999.96 6063.78 6001.86 -371.80 5990.33 2.18 5959207.62 618043.72 N 70 17 50.096 W 149 2 38.667 11741.06 96.70 107.20 8857.88 8942.44 6029.95 6094.73 6032.04 -380.58 6020.02 9.34 5959199.29 618073.53 N 70 17 50.010 W 149 2 37.802 11773.34 93.77 108.80. 8854.93 8939.49 6060.86 6126.87 6063.18 -390.51 6050.59 10.33 5959189.81 618104.24 N 70 17 49.912 W 149 2 36.911 11805.29 88.52 109.13 8854.29 8938.85 6091.42 6158.81 6093.99 -400.89 6080.79 16.46 5959179.89 618134.58 N 70 17 49.809 W 149 2 36.031 SurveyEditor Ver SP 1.0 Bld( doc40x_56) W-17\W-17\W-17A\W-17A Generated 9/26/2005 1:52 PM Page 8 of 9 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latkude Longitude • Depth Section Departure ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS 1 IOJa.oo oJ.oa Ilvao ooooao oa41.14 oIG4.lV blli3.-11 blLb.`Jb -4IL.bJ bl-IS.UD l4.GV by5ylbt3J3 b~li5lb/.UZ IV/U"I/4y.li`9b VV l4yL3b.Uy"I 11872.00 81.22 112.13 8860.78 8945.34 6154.35 6225.15 6157.53 -424.19 6142.90 9.46 5959157.51 618197.03 N 70 17 49.580 W 149 2 34.221 11900.25 81.08 112.40 8865.13 8949.69 6180.56 6253.07 6184.03 -434.77 6168.73 1.07 5959147.32 618223.02 N 70 17 49.475 W 149 2 33.468 11935.30 80.87 111.66 8870.62 8955.18 6213.10 6287.68 6216.96 -447.75 6200.82 2.17 5959134.82 618255.29 N 70 17 49.347 W 149 2 32.533 11967.18 80.52 110.98 8875.78 8960.34 6242.81 6319.14 6247.03 -459.19 6230.13 2.37 5959123.82 618284.76 N 70 17 49.235 W 149 2 31.679 11996.07 80.10 108.63 8880.64 8965.20 6269.94 6347.62 6274.46 -468.84 6256.92 8.15 5959114.57 618311.69 N 70 17 49.140 W 149 2 30.898 12030.79 80.25 105.49 8886.57 8971.13 6302.99 6381.83 6307.82 -478.88 6289.62 8.92 5959105.03 618344.54 N 70 17 49.041 W 149 2 29.946 12063.06 80.04 104.78 8892.09 8976.65 6333.96 6413.63 6339.06 -487.18 6320.31 2.26 5959097.19 618375.35 N 70 17 48.959 W 149 2 29.051 12091.67 79.69 105.02 8897.13 8981.69 6361.43 6441.79 6366.75 -494.42 6347.53 1.48 5959090.35 618402.66 N 70 17 48.887 W 149 2 28.258 12126.28 79.03 104.61 8903.52 8988.08 6394.61 6475.81 6400.22 -503.12 6380.41 2.23 5959082.15 618435.67 N 70 17 48.802 W 149 2 27.300 12156.79 78.99 106.50 8909.33 8993.89 6423.74 6505.76 6429.61 -511.15 6409.26 6.08 5959074.55 618464.64 N 70 17 48.722 W 149 2 2 9 12187.09 78.47 106.00 8915.25 8999.81 6452.55 6535.47 6458.71 -519.46 6437.79 2.36 5959066.66 618493.28 N 70 17 48.640 W 149 2 12219:48 78.57 106.75 8921.70 9006.26 6483.31 6567.21 6489.79 -528.41 6468.24 2.29 5959058.17 618523.87 N 70 17 48.552 W 149 2 24.740 12253.63 81.15 105.04 8927.71 9012.27 6515.96 6600.83 6522.77 -537.62 6500.57 9.02 5959049.45 618556.32 N 70 17 48.461 W 149 2 23.798 12282.46 81.88 105.01 8931,97 9016.53 6543.75 6629.34 6550.82 -545.01 6528.11 2.53 5959042.47 618583.97 N 70 17 48.388 W 149 2 22.995 12317.34 81.32 105.63 8937.06 9021.62 6577.34 6663.85 6584.75 -554.12 6561.39 2.38 5959033.85 618617.38 N 70 17 48.298 W 149 2 22.026 12349.67 80.87 105.21 8942.07 9026.63 6608.43 6695.79 6616.15 -562.62 6592.18 1.89 5959025.82 618648.29 N 70 17 48.215 W 149 2 21.128 12377.66 80.70 105.98 8946.55 9031.11 6635.29 6723.42 6643.29 -570.04 6618.79 2.78 5959018.79 618675.00 N 70 17 48.141 W 149 2 20.353 12412.33 80.77 105.16 8952.13 9036.69 6668.57 6757.63 6676.93 -579.23 6651.75: 2.34 5959010.09 618708.10 N 70 17 48.051 W 149 2 19.392 Last MWD+IFR+MS 12445.02 80.56 106.01 8957.43 9041.99 6699.94 6789.89 6708.63 -587.90 6682.83 2.64 5959001.89 618739.29 N 70 17 47.965 W 149 2 18.487 TD (Projected) 12500.09 80.56 106.01 8966.47 9051.03 6752.67 6844.21 6761.97 -602.88 6735.04 0.00 5958987.69 618791.72 N 70 17 47.817 W 149 2 16.965 Survey Type: Definitive Survey NOTES: GCT MS - (Schlumberger GCT multishot -- GCT surveys in casing o r open hole. GCT = "Gyro Continuous Tool", ) MWD +IFR + MS - (In-field referen ced MWD w ith mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correction is app lied to enhance inclination accuracy. ) Lestal Description: Northing (Y) [ftUS] Easting ( X) [ftUS] Surface : 4513 FSL 1183 FEL S21 T11 N R12E UM 5959490.04 61 2049.03 BHL : 3907 FSL 5009 FEL S23 T11 N R12E UM 5958987.69 618791.72 SurveyEdiior Ver SP 1.0 B1d( doc40x_56) W-17\W-17\W-17A\W-17A Generated 9/26/2005 1:52 PM Page 9 of 9 W-17A Actual Completion 13 3/8", 72.0#, 2,854 L-80, ID = 12.347" /. = = Pre rig cement PS~A 11,000 From DRLG - DRAF 2,218 --~4 1/2"'X' landing nipple TREE= 41/16" WELLHEAD= MCEVOY ACTUATOR= __ OTIS KB. ELEV = 81.62' BF. ELEV = KOP = Max Angle = __53.71' 1484' 52 @ 11848' Datum MD = 11492' Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VALVE LATCH 2 1 3560 5589 3216 4750 39 32 4 1/2" X 1" KBG-2 4 1/2" X 1" KBG-2 DCK DMY BK BK 5,240 Window in 9 5/8" casin 5,657 4 1/2"'X' landing nipple 5,678 7" x a 1/z"'Baker s-3 Pkr 5,702 4 1/2"'X' landing nipple 5,723 41/2"'XN'landin nip le 5,735 - 4 1/2" WLEG 5,728 -~ 7 X 5" Baker Flex Lok liner hanger ZXP liner top packer w / TBS 5,829 Squeeze perfs 15' 6 spf 5,884 Squeeze perfs 15' @ 6 spf 10,180 7" X 5" Baker Flex Lok liner hanger ZXP liner top packer w / TBS 10,330 ~", 26.0#, L-80 BTC-M casing TOP OF 7" LNR~ 11,160 3112", 9.2#, L-80, 11,195 ID = 2.992" s 5/a", a7.o#, 11,417 L-80, ID = 8.681" 4 1 /2", 12.6#, L-80, 10,179 TGII tubing 12,498 4 1/2", 12.6#, L-80, IBT-M liner STD 11,932 7", 2s.o#, L-8o, 11,973 U4S liner PRUDHOE BAY UN(f WELL: W-17A PERMfT No: API No: 50-029-21856-01 SC-C 21, T11 N, R12E, 766' FNL 8 1183' FEL BP 6cploration (Alaska) ~~ ~ ?~(~~ SCHLUMBERGER ~tlas~~ [7[~ ~~€ ~,~ C~_,:~~~.. , ..~; .:.: Survey report 541] Ac~c;~tR; ~.;;~' Client ...................: BP Exploration (Alaska) Inc. Field ..................... Prudhoe Bay-WOA Well ...................... W-17A API number ...............: 50-029-21856-01 Engineer .................. S. Moy Rig :.....................: Nabors 7ES STATE :...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ---- Permanent datum..........: Depth reference..........: GL above permanent.......: KB above permanent........ DF above permanent.......: ------------------ Mean Sea Level Driller's Pipe Tally 30.85 ft N/A Top Drive ft 84.56 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 92.11 degrees [(c)2005 IDEAL ID10 2C O1] 19-Sep-2005 14:53:15 Page 1 of 12 Spud date ................. O1-Sep-05 Last survey date.........: 19-Sep-05 Total accepted surveys...: 330 MD of first survey.......: 0.00 ft MD of last survey........: 12500.09 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date ............: 08-Sep-2005 Magnetic field strength..: 1151.67 HCNT Magnetic dec (+E/W-).....: 24.59 degrees Magnetic dip .............. 80.84 degrees ----- MWD survey Reference Reference G ............... Reference H ..............: Reference Dip ............: Tolerance of G............ Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 1151.67 HCNT 80.84 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.59 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.59 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • • 0'~C~ ~~ ~ ~ ~, k. SCHLUMBERGER Survey Report 19-Sep-2005 14:53:15 Page 2 of 12 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- .displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (f t) (ft) (deg) 100f) type (deg) 1 5207.26 43.50 86.93 34.80 4482.17 2152.09 180.43 2160.20 2167.72 85.23 1.17 TIP No ne 2 5333.86 38.31 87.44 126.60 4577.82 2234.65 184.52 2242.97 2250.55 85.30 4.11 Inc Onl y 3 5429.59 37.71 87.87 95.73 4653.24 2293.43 186.93 2301.87 230.9.45 85.36 0.69 Inc Onl y 4 5525.24 37.08 88.34 95.65 4729.23 2351.37 188.85 2359.93 2367.47 85.42 0.72 MWD IFR MS 5 5621.26 32.13 90.03 96.02 4808.24 2405.81 189.68 2414.43 2421.87 85.51 5.25 MWD _IFR _MS 6 5716.20 29.79 89.68 94.94 4889.65 2454.61 189.80 2463.27 2470.57 85.59 2.47 MWD _IFR _MS 7 5812.13 25.51 91.56 95.93 4974.61 2499.09 189.37 2507.77 2514.91 85.68 4.55 MWD - IFR - MS • 8 5906.98 20.81 95.84 94.85 5061.80 2536.35 187.10 2544.97 2551.84 85.80 5.26 MWD _IFR _MS 9 6002.21 20.80 99.24 95.23 5150.82 2570.01 182.66 2578.49 2584.95 85.95 1.27 MWD IFR MS 10 6098.30 20.68 99.23 96.09 5240.68 2603.78 177.20 2612.07 2618.08 86.12 0.12 MWD_ IFR _MS 11 6194.19 20.31 95.77 95.89 5330.51 2637.19 172.81 2645.34 2650.98 86.26 1.32 MWD_ IFR _MS 12 6290.01 19.94 95.67 95.82 5420.48 2670.09 169.52 2678.15 2683.51 86.38 0.39 MWD_ IFR _MS 13 6385.54 19.59 95.26 95.53 5510.38 2702.34 166.45 2710.31 2715..41 86.49 0.39 MWD_ IFR _MS 14 6480.71 19.56 95.96 95.17 5600.05 2734.17 163.33 2742.04 2746.90 86.59 0.25 MWD IFR MS 15 6576.74 18.71 96.11 96.03 5690.77 2765.57 160.02 2773.34 2777.96 86.70 0.89 MWD_ IFR _MS 16 6672.67 20.01 92.89 95.93 5781.28 2797.33 157.56 2805.04 2809.46 86.79 1.75 MWD_ IFR _MS 17 6769.18 19.50 93.82 96.51 5872.11 2829.94 155.65 2837.60 2841.86 86.86 0.62 MWD_ IFR _MS 18 6865.72 18.97 93.67 96.54 5963.26 2861.74 153.57 2869.34 .2873.44 86.94 0.55 MWD_ IFR _MS 19 6973.16 19.83 93.43 107.44 6064.60 2897.41 151.36 2904.95 2908.89 87.02 0.80 MWD IFR MS 20 7068.46 18.66 93.37 95.30 6154.57 2928.81 149.50 2936.31 2940.11 87.09 1.23 MWD IFR MS 21 7164.08 18.51 91.75 95.62 6245.20 2959.29 148.14 2966.75 2970.45 87.14 0.56 _ MWD_ IFR _ _MS • 22 7259.60 19.23 91.02 95.52 6335.59 2990.18 147.39 2997.64 3001.26 87.19 0.79 MWD_ IFR MS ! 23 7354.57 20..54 91.11 94.97 6424.89 3022.47 146.79 3029.93 3033.49 87.23 1.38 MWD_ IFR _MS 24 7450.17 20.98 93.68 95.60 6514.29 3056.35 145.37 3063.78 3067.23 87.28 1.06 MWD IFR MS 25 7545.73 19.10 92.71 95.56 6604.06 3089.09 143.53 3096.47 3099.80 87.35 2.00 MWD_ IFR _MS 26 7641.29 19.48 94.48 95.56 6694.26 3120.64 141.55 3127.97 3131.17 87.41 0.73 MWD_ IFR _MS 27 7736.44 21.14 96.20 95.15 6783.49 3153.61 138.46 3160.85 3163'.88 87.49 1.85 MWD_ IFR _MS 28 7831.90 20.36 96.88 95.46 6872.75 3187.33 134.61 3194.45 3197.29 87.59 0.86 MWD_ IFR _MS 29 7927.87 18.84 96.81 95.97 6963.16 3219.41 130.77 3226.41 3229.06 87.68 1.58 MWD IFR MS [(c)2005 IDEAL ID10 2C 01) SCHLUMBERGER Survey Report 19-Sep-2005 14:53:15 Page 3 of 12 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/w- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (f t) --------- (ft) ------- (deg) -------- 100f) ----- type ----- (deg) ------ --- 30 -------- 8023.03 ------ 22.09 ------- 95.18 ------ 95.16 -------- 7052.30 -------- 3252.60 ------- 127.33 --------- 3259.50 ------- 3261.98 -------- 87.76 ----- 3.47 -- MWD --- _IFR ------ _MS 31 8118.83 25.35 93.50 95.80 7140.00 3291.10 124.45 3297.92 3300.27 87.84 3.47 MWD_ IFR _MS 32 8211.83 29.87 91.58 93.00 7222.39 3334.19 122.60 3340.96 3343.21 87.90 4.95 MWD_ IFR _MS 33 8308.73 33.89 92.43 96.90 7304.66 3385.35 120.79 3392.10 3394.25 87.96 4.17 MWD_ IFR _MS 34 8400.98 38.72 94.64 92.25 7378.98 3439.93 117.36 3446.59 3448.58 88.05 5.42 MWD IFR MS 35 8499.18 42.18 95.82 98.20 7453.70 3503.53 111.53 3510.02 3511.79 88.18 3.61 MWD_ IFR_ MS 36 8595.29 42.67 95.47 96.11 7524.64 3568.24 105.15 3574.54 3576.09 88.32 0.57 MWD_ IFR MS 37 8691.51 42.24 95.99 96.22 7595.63 3633.06 98.67 3639.16 3640.50 88.45 0.58 MWD_ IFR_ MS 38 8787.21 41.92 96.73 95.70 7666.66 3697.02 91.57 3702.90 3704.04 88.58 0.62 MWD_ IFR_ MS 39 8882.52 43.28 96.27 95.31 7736.82 3761.34 84.27 3767.00 3767.94 88.72 1.46 MWD IFR MS 40 8978.36 42.80 96.67 95.84 7806.87 3826.57 76.90 3832.00 3832.77 88.85 0.58 MWD_ IFR_ MS 41 9074.12 42.38 96.95 95.76 7877.37 3891.15 69.21 3896.34 3896.96 88.98 0.48 MWD_ IFR_ MS 42 9169.88 41.40 97.17 95.76 7948.65 3954.85 61.36 3959.80 3960.27 89.11 1.03 MWD_ IFR_ MS 43 9265.49 42.48 97.53 95.61 8019.77 4018.49 53.18 4023.17 4023.52 89.24 1.16 MWD_ IFR_ MS 44 9361.38 43.49 97.01 95.89 8089.92 4083.60 44.91 4088.02 4088.27 89.37 1.12 MWD IFR MS 45 9456.06 42.62 97.71 94.68 8159.10 4147.96 36.63 4152.13 4152.29 89.49 1.05 MWD_ IFR_ MS 46 9551.36 43.00 96.58 95.30 8229.01 4212.48 28.58 4216.39 4216.48 89.61 0.90 MWD_ IFR_ MS 47 9647.61 42.92 96.60 96.25 8299.45. 4277.87 21.05 4281.55 4281.60 89.72 0.08 MWD_ IFR_ MS 48 9744.28 43.19 96.37 96.67 8370.09 4343.67 13.60 4347.12 4347..14 89.82 0.32 MWD_ IFR_ MS 49 9838.66 43.46 94.12 94.38 8438.75 4408.32 7.68 4411.60 4411.61 89.90 1.66 MWD IFR MS 50 9934.83 41.87 95.53 96.17 8509.47 4473.42 2.21 4476.54 4476.54 89.97 1.93 MWD_ IFR_ MS 51 10029.71 41.61 94.15 94.88 8580.26 4536.51 -3.12 4539.48 4539.48 90.04 1.01 MWD_ IFR_ MS 52 10125.81 42.49 92.95 96.10 8651.63 4600.86 -7.10 4603.72 4603.72 90.09 1.24 MWD_ IFR_ MS 53 10221.16 43.46 94.99 95.35 8721.39 4665.81 -11.61 4668.55 4668.56 90.14 1.78 MWD_ IFR_ MS 54 10267.99 46.24 94.62 46.83 8754.59 4698.80 -14.37 4701.46 4701.48 90.18 5.96 MWD IFR MS 55 10339.62 45.82 94.33 71.63 8804.32 4750.31 -18.39 4752.85 4752.89 90.22 0.65 Inc Only 56 10371.23 47.98 95.29 31.61 8825.92 4773.36 -20.33 4775.85 4775.89 90.24 7.18 MWD_ IFR_ MS 57 10403.87 50.26 98.05 32.64 8847.28 4797.95 -23.21 4800.35 4800.41 90.28 9.47 MWD_ IFR_ MS 58 10435.02 52.51 99.75 31.15 8866.72 4822.12 -26.98 4824.40 4824.47 90.32 8.39 MWD_ IFR_ MS 59 10467.25 55.33 101.73 32.23 8885.70 4847.87 -31.84 4849.98 4850.09 90.38 10.06 MWD IFR MS • • [(c)2005 IDEAL ID10 2C Ol] SCHLUMBERGER Survey Report 19-Sep-2005 14:53:15 Page 4 of 12 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- . (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (f t) --------- (f t) ------- (deg) -------- 100f) ----- type. ----- (deg) ------ --- 60 -------- 10497.93 ------ 57.50 ------- 102.14 ------ 30.68 -------- 8902.67 -------- 4873.05 ------- -37.13 --------- 4874.99 ------- 4875.13 -------- 90.44 ----- 7.16 -- MWD --- _IFR ------ _MS 61 10533.17 59.98 104.41 35.24 8920.96 4902.59 -44.05 4904.30 4904.50 90.51 8.93 MWD _IFR _MS 62 10562.65 61.43 104.61 29.48 8935.38 4927.70 -50.49 4929.19 4929.45 90.59 4.95 MWD _IFR _MS 63 10597.04 60.33 104.91 34.39 8952.12 4957.02 -58.15 4958.24 4958.58 90.67 3.29 MWD _IFR _MS 64 10629.33 60.32 105.59 32.29 8968.10 4984.34 -65.53 4985.31 4985.74 90.75 1.83 MWD IFR MS 65 10657.70 62.20 106.42 28.37 8981.75 5008.48 -72.39 5009.21 5009.74 90.83 7.11 MWD _IFR _MS 66 10692.36 64.80 107.07 34.66 8997.21 5038.49 -81.32 5038.91 5039.57 90.92 7.69 MWD _IFR _MS 67 10724.74 66.50 107.36 32.38 9010.56 5066.97 -90.05 5067.09 5067.89 91.02 5.31 MWD _IFR _MS 68 10754.11 68.91 109.28 29.37 9021.70 5093.06 -98.60 5092.88 5093.84 91.11 10.19 MWD _IFR _MS 69 10787.61 72.25 109.24 33.50 9032.84 5123.25 -109.02 5122.71 5123.86 91.22 9.97 MWD IFR MS 70 10819.60 74.58 109.70 31.99 9041.97 5152.51 -119.24 5151.61 5152.99 91.33 7.41 MWD _IFR _MS 71 10848.38 76.81 110.86 28.78 9049.08 5179.00 -128.90 5177.76 5179.37 91.43 8.68 MWD _IFR _MS 72 10880.49 79.69 111.09 32.11 9055.62 5208.75 -140.16 5207.12 5209.00 91.54 9.00 MWD _IFR _MS 73 10915.53 82.50 111.42 35.04 9061.04 5241.44 -152.70 5239.38 5241.60 91.67 8.07 MWD_ IFR _MS 74 10943.50 84.43 110.61 27.97 9064.22 5267.73 -162.67 5265.31 5267.83 91.77 7.48 MWD IFR MS 75 10978.23 87.15 109.98 34.73 9066.77 5300.64 -174.68 5297.80 5300.68 91.89 8.04 MWD_ IFR _MS 76 11011.37 90.03 109.06 33.14 9067.59 5332.24 -185.75 5329.02 5332.25 92.00 9.12 MWD IFR MS 77 11039.57 92.02 108.46 28.20 9067.08 5359.26 -194.82 5355.71 5359.26 92.08 7.37 MWD_ IFR _MS 78 11074.49 95.25 106.79 34.92 9064.87 5392.83 -205.37 5388.92 5392.83 92.18 10.41 MWD_ IFR _MS 79 11106.39 97.50 106.36 31.90 9061.33 5423.53 -214.41 5419.31 5423.55 92.27 7.18 MWD IFR MS 80 11134.74 100.00 105.25 28.35 9057.02 5450.75 -222.04 5446.26 5450.79 92.33 9.63 MWD_ IFR _MS 81 11166.96 101.91 105.13 32.22 9050.89 5481.56 -230.33 5476.79 5481.63 92.41 5.94 MWD_ IFR _MS 82 11199.33 102.17 105.03 32.37 9044.14 5512.41 -238.57 5507.36 5512.52 92.48 0.86 MWD_ IFR _MS 83 11231.42 101.71 105.13 32.09 9037.50 5543.00 -246.74 5537.67 5543.17 92.55 1.47 MWD_ IFR _MS 84 11262.59 101.95 105.06 31.17 9031.11 5572.73 -254.68 5567.13 5572.95 92.62 0.80 MWD IFR MS 85 11295.05 101.67 106.25 32.46 9024.47 5603.62 -263.25 5597.72 5603.91 92.69 3.69 MWD_ IFR _MS 86 11327.34 101.32 106.45 32.29 9018.04 5634.29 -272.16 5628.08 5634.66 92.77 1.24 MWD_ IFR _MS 87 11358.53 100.80 106.30 31.19 9012.05 5663.96 -280.79 5657.45 5664.42 92.84 1.73 MWD_ IFR _MS 88 11390.60 100.73 106.50 32.07 9006.06 5694.49 -289.69 .5687.68 5695.05 92.92 0.65 MWD_ IFR _MS 89 11422.64 101.78 105.06 32.04 8999.81 5725.02 -298.23 5717.91 5725.69 92.99 5.49 MWD IFR MS • • [(c)2005 IDEAL ID10 2C O1] SCHLUMBERGER Survey Report 19-Sep-2005 14:53:15 Page 5 of 12 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (f t) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 90 11453.57 101.64 104.12 30.93 8993.53 5754.59 -305.86 5747.22 5755.36 93.05 3.01 MWD_ IFR _MS 91 11486.33 101.49 104.53 32.76 8986.96 5785.96 -313.80 5778.32 5786.84 93.11 1.31 MWD_ IFR _MS 92 11518.65 101.15 104.68 32.32 8980.62 5816.90 -321.79 5808.99 5817.90 93.17 1.15 MWD_ IFR _MS 93 11549.83 100.90 105.18 31.18 8974.66 5846.74 -329.68 5838.56 5847.86 93.23 1.77 MWD_ IFR _MS 94 11581.98 100.56 104.97 32.15 8968.67 5877.52 -337.89 5869.06 5878.78 93.30 1.24 MWD IFR MS 95 11614.19 99.89 105.39 32.21 8962.95 5908.40 -346.19 5899.65 5909.80 93.36 2.44 MWD_ IFR _MS 96 11645.92 99.79 106.26 31.73 8957.53 5938.77 -354.72 5929.73 5940.33 93.42 2.72 MWD _ IFR MS 97 11677.63 99.89 105.49 31.71 8952.11 5969.12 -363.27 5959.78 5970.84 93.49 2.41 - MWD IFR - MS . 98 11709.80 99.23 105.73 32.17 8946.77 5999.96 -371.80 5990.33 6001.86 93.55 2.18 MWD_ IFR _MS 99 11741.06 96.70 107.20 31.26 8942.44 6029.95 -380.58 6020.02 6032.04 93.62 9.34 MWD IFR MS 100 11773.34 93.77 108.80 32.28 8939.49 6060.86 -390.51 6050.59 6063.18 93.69 10.33 MWD_ IFR_ MS 101 11805.29 88.52 109.13 31.95 8938.85 6091.42 -400.89 6080.79 6093.99 93.77 16.46 MWD_ IFR_ MS 102 11839.68 83.85 110.56 34.39 8941.14 6124.10 -412.53 6113.05 6126.96 93.86 14.20 MWD_ IFR_ MS 103 11872.00 81.22 112.13 32.32 8945.34 6154.35 -424.19 6142.90 6157.53 93.95 9.46 MWD_ IFR_ MS 104 11900.25 81.08 112.40 28.25 8949.69 6180.56 -434.77 6168.73 6184.03 94.03 1.07 MWD IFR MS 105 11935.30 80.87 111.66 35.05 8955.19 6213.10 -447.75 6200.82 6216.96 94.13 2.17 MWD IFR_ MS 106 11967.18 80.52 110.98 31.88 8960.34 6242.81 -459.19 6230.13 6247.03 94.22 2.37 _ MWD_ IFR_ MS 107 11996.07 80.10 108.63 28.89 8965.20 6269.94 -468.84 6256.92 6274.46 .94.29 8.15 MWD_ IFR_ MS 108 12030.79 80.25 105.49 34.72 8971.13 6302.99 -478.88 6289.62 6307.82 94.35 8.92 MWD_ IFR_ MS 109 12063.06 80.04 104.78 32.27 8976.65 6333.96 -487.18 6320.31 6339.06 94.41 2.26 MWD IFR MS 110 12091.67 79.69 105.02 28.61 8981.69 6361.43 -494.42 6347.53 6366.75 94.45 1.48 MWD IFR MS 111 12126.28 79.03 104.61 34.61 8988.08 6394.61 -503.12 6380.41 6400.22 94.51 2.23 _ MWD_ _ IFR_ MS • 112 12156.79 78.99 106.50 30.51 8993.89 6423.74 -511.15 6409.26 6429.61 94.56 6.08 MWD_ IFR_ MS 113 12187.09 78.47 106.00 30.30 8999.82 6452.55 -519.46 6437.79 6458.71 94.61 2.36 MWD_ IFR_ MS 114 12219.48 78.57 106.75 32.39 9006.26 6483.31 -528.41 6468.25 6489.79 94.67 2.29 MWD IFR MS 115 12253.63 81.15 105.04 34.15 9012.27 6515.96 -537.62 6500.57 6522.77 94.73 9.02 MWD_ IFR_ MS 116 12282.46 81.88 105.01 28.83 9016.53 6543.75 -545.01 6528.11 6550.82 94.77 2.53 MWD_ IFR_ MS 117 12317.34 81.32 105.63 34.88 9021.62 6577.34 -554.12 6561.39 6584.75 94.83 2.38 MWD_ IFR_ MS 118 12349.67 80.87 105.21 32.33 9026.63 6608.43 -562.62 6592.18 6616.15 94.88 1.89 MWD_ IFR_ MS 119 12377.66 80.70 105.98 27.99 9031.11 6635.29 -570.04 6618.79 6643.30 94.92 2.78 MWD IFR MS [(c)2005 IDEAL ID10 2C O1] ,SCHLUMBERGER Survey Report 19-Sep-2005 14:53:15 Page 6 of 12 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/w- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft). (ft) (ft) (ft) (ft) (deg). 100f) type (deg) 120 12412.33 80.77 105.16 34.67 9036.69 6668.57 -579.23 6651.76 6676.93 94.98 2.34 MWD_IFR_MS 121 12445.02 80.56 106.01 32.69 9042.00 6699.94 -587.90 6682.83 6708.63 95.03 2.64 MWD IFR_MS 122 12500.09 80.56 106.01 55.07 9051.03 6752.67 -602.88 6735.04 6761.97 95.12 0.00 Projected to TD [(c)2005 IDEAL ID10 2C O1] • • ~,~~ '''~ ~I~ • • Subject: W-17A From: "Gagliardi, Shane T" <gaglst@BP.com> Date: Thu, 29 Sep 2005 11:17:01 -0800 To: winton_aubert@admin.state.ak.us CC: "Wesley, Dave E" <WesleyDE@BP.com> Winton, Here is the diagram that you requested for W-17a when we discussed the squeeze options on 9/22/05. The squeeze was performed due to internal reservoir management concerns. Since this is an injector, we will need the variance for the injection packer above the perfs. I have included the section of the regs that state the packer setting depths. We felt that this option would give us the most robust well integrity and accomplish our reservoir management goals in the Schrader. 20 AAC 25.412 CASING, CEMENTING, AND TUBING OF INJECTION WELLS FOR ENHANCED RECOVERY, DISPOSAL, AND STORAGE. (a) A well used for injection must be cased and cemented in accordance with 20 AAC 25.030 to prevent leakage into oil, gas, or freshwater sources. (b) A well used for injection must be equipped with tubing and a packer, or with other equipment that isolates pressure to the injection interval, unless the commission approves the operator's use of alternate means to ensure that injection of fluid is limited to the injection zone. The minimum burst pressure of the tubing must exceed the maximum surface injection pressure by at least 25 percent. The packer must be placed within 200 feet measured depth above the top of the perforations, unless the commission approves a different ptacemen# depth as the commission considers appropriate given the thickness and depth of the confining zone. Thanks, Shane «W-17A Proposed Comp w squeeze.ZlP» W-17A Proposed Comp w squeeze.ZlP Content-Description: W-17A Proposed Comp w squeeze.ZlP Content-Type: application/x-zip-compressed Content-Encoding: base64 W-17A Prop~ed Completion 2,200 4 1/2"'X' landing nipple 13 3/8", 72.0#, L-80, ID = 12.347" 2'854 10,330 r', 2s.o#, L-80 BTC-M casing 5,240 Window in 9 5I8" casing Pre rig cerrr~nt P8,A 11,000 TOP OF 7" LNR - 11,160 3 1/2^, 9.2#; L-80, 11,195 ID = 2.992" 9 5/8^, a7.o#, 11,417 L-80,ID = 8.681" PBTD 11,932 7", 26.0#, L-so, 11,973 U4S liner 12,500 4 1/2", 12.6#, L-80, IBT-M liner TREE = 4 1/16" WELLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 81.62' BF. ELEV = 53.71' KOP = 1484' Max Angle = 52 @ 11848' Datum MD = 11492' ~,U.~.~ .. ~ =,;,,, bS DATE REV BY COMMENTS DATE REV BY COMMENTS 9188 ORIGINAL COMPLETION 10/20/02 PP/KAK CORRECTIONS 10/16!90 JQ ORIGINAL COMPLETION 07/21!05 dew Proposed corr~letion Wp04 02/09/01 SIS-QAA CONVERTEDTOCANVAS 03105101 SIS-LG FINAL 09/05/01 RN/TP CORRECTIONS PRUDHOE BAY UNIT WELL: W-17A PERMIT No: API No: 50-029-21856-01 SEC 21, T11 N; R12E, 766' FNL & 1183' FEL GAS LIFT MANDRELS ST MD TVD DEV TYPE VALVE LATCH 2 1 5580 3551 4 1/2" X 1" KBG-2 4 1/2" X 1" KBG-2 DMY DMY BK BK 5,643 4 1!2" 'X' landing nipple 5,666 7" x 4 1/z"'Baker s-s Pkr 5,887 4 1/2"'X' landing nipple 5,708 4 1!2"'XN' landing nipple 5,721 7" X 5" Baker Flex Lok liner hanger ZXP liner top packer w /TBS ~ ~ ' ('''~/~ 5,829 Squeeze perfs 15' @ 6 spf "~ = 5,884 Squeeze perfs 15' @ 6 spf i i 10,180 7" X 5" Baker Flex Lok liner hanger ZXP liner top packer w {TBS 4 1!2", 12.6#, L-80, 10,222 TGII tubing ~77 p ALA.$KA OIL A11TD GAS C01~5ERQATIOI~T COMD'IISSIOIQ Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: PBU W-17A BP Exploration (Alaska), Inc. Permit No: 205-122 Surface Location: 766' FNL, 1183' FEL, Sec. 21, T11N, R12E, UM Bottomhole Location: 1271' FNL, 99' FWL, Sec. 23, T11N, R12W, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill 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 ess any required test. Contact the Commission's petroleum field inspecto~;~~1t'('9'O5~ 659/~'~~~ger). DATED this ®!/day of August, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~~ '3fi~ STATE OF ALASKA ALASKA AND GAS CONSERVATION COM ISSION PERMIT TO DRILL ~ 20 AAC 25.005 AUG 0 ~ 2i1D5 ia. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ^~@ ve opment Oil ^ Multiple Zone ^ Stratigraphic Test ®Service ^ ~ii1@~pr~~s ~ g 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. ._ ~, 11. Well Name_ ber: ~~(1~f3 ~~ BU VIA lf~ejeas 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: ~. MD 12324 ' TVD 9067 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ~ .. 766' FNL i 183' FEL SEC 21 T11 N R12E UM ' 7. Property Designation: '~~t" ~ ADL 047451 ~ ~•~- ~ ~~ ~" Pool , , . , , , Top of Productive Horizon: 813' FNL, 3778' FWL, SEC. 22, T11 N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 25, 2005 ~ Total Depth: 1271' FNL, 99' FWL, SEC. 23, T11N, R12E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 17,500' 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 612049 ~ y- 5959491 Zone- ASP4 10. KB Elevation (Height above GL): 81.6' feet 15. Distance to Nearest Well Within Pool W-21 A is 786' away 16. Deviated Wells: Kickoff Depth: 5300 ~ feet Maximum Hole Angle: 104 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3400 ° Surtace: 2520 18. acing rogram: Size Specfficatbns Setting Depth To Bottom uantity o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M 5377' 5000' 4328' 10377' 8832' 14 cu ft LiteCrete, 197 cu ft Class'G' 8.681" 7" 26# L-80 BTC-M 5000' Surface Surtace 5000' 4328' ieback Liner 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1947' 10227' 8721' 1232 ' 9067' 09 cu ft Class'G' 19. PRESENT W ELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 11973 Total Depth TVD (ft): 9185 Plugs (measured): 11162 Effective Depth MD (ft): 11162 Effective Depth TVD (ft): 8669 Junk (measured): None Casin Len h Size Cement Volume MD TVD r r 110' 20" cu ds Concrete 110' 110' 2854' 13-3/8" 128 cu ft Permafrost 2854' 2686' 11417' 9-5/8" 465 cu ft Class 'G' 11417' 8833' 813' 7" 53 cu ft Class 'G' 11160' - 11973' 8668' - 9185' Perforation Depth MD (ft): 11627' - 11720' Perforation Depth TVD (ft): 8969' - 9028' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ 13iverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Wesley, 564-5153 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number. Si nature sr Phone 564-4166 Date ~' 3 Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: ,~S' j2. API Number: 50- 029-21856-01-00 Permit Approv Date: ~ " See cover letter for other requirements Conditions of Approval: Sam equired ^ Yes ~No Mud Log Requir d [~ Yes ~No Hy oge Sulfide Measures Yes L1 No Directional Survey Required Yes LJ No Other:T~e5~~ ~j~ ~~ ~ ~'tat~ ~Sl . /~ ~T' 8f ~+-i~e,~.4~ ~~'~e~j ~v~ r~ ~a-~i~ ~, 1 APPROVED BY A ro d ~ THE COMMISSION Date Form 10-4ai"rB~sed /2 4 ''~ - ~(lbmit/(n Duplicate • Well Name: W-17A Planned Well Summary Horizontal Target Well W-17A Well Type Sidetrack Ivishak Z4 In'ector Objective AFE Number: PBD 4P2411 Surface Northin Eastin Offsets TRS Location 5,959,491.04 612,049.03 766' FNL / 1,182' FEL 11 N, 12 E, 21 API Number: 50-029-21856-01 Target Northin Eastin Offsets TRS Location 5,959,520.00 617,010.00 813' FNL / 1,501' FEL 11 N, 12 E, 22 Bottom Northin Eastin Offsets TRS Location 5,959,086.00 618,618.00 1,271' FNL / 99' FWL 11 N, 12 E, 23 Planned KOP: 5,300' and / 4,548' tvd Planned TD: 12,324' and / 9,067' tvd Ri Nabors 7ES 1 CBE: 52.77' RTE: 81.27' Planned S ud Date: 08/25/2005 Planned O eratin Da s: 27.4 days Directional Program i i A roved Well Ian: W p04 Exit oint: 5,300' and / 4,467' sstvd Maximum Hole Inclination: 104.0° from 11,125' to 11,375' in the planned 6 1/8" production section. Proximity Issues: There are no close approach issues. All surrounding wells pass mayor risk criteria. Survey Program: Standard MWD with IIFR /Cassandra. Nearest Well within ool: Well W-21 A, with center-to-center distance of 786' at 12,289'md. Nearest Pro a Line 17,500' to the nearest PBU propert line. W-17A Sidetrack Page 1 • • Logging Program Hole Section: Required Sensors /Service 8'h" intermediate: Real time MWD Dir/GR/Res/PWD throu hout the interval. 6 %8" roduction: R ti a MWD Dir/GR/Res/AIM throu hout the interval. Two sam le catchers. Cased Hole: SI in the 9 5/" intermediate casin ost de-com letion and in the 7" drillin liner. O en Hole: a tanned Mud Program Hole Section / o eration: Mill section in the 9 5/d' casin from 5,250' to 5,375'. T e Densit Viscosit PV YP Tau 0 API FL H LSND 9.0 50-60 12-18 50-60 3-7 6-8 8.5-9.5 Hole Section / o eration: Drillin 8'/z" intermediate to above HRZ. T e Densit Viscosit PV YP Tau 0 API FL H LSND 9.0- 10.4 35-50 12-18 20-26 3-7 3-4 9.0-9.5 Hole Section / o eration: Drillin 8'/z" intermediate HRZ to Kin ak. T e Densit Viscosit PV YP Tau 0 API FL H LSND 10.4-10.9 35-50 12-18 20-26 3-7 3-4 9.0-9.5 Hole Section / o eration: Drillin 8'/2" intermediate Kin ak to Top Sa River. T e Densit Viscosit PV YP Tau 0 API FL H LSND 0.9 35-50 12-18 20-26 3-7 3-4 9.0-9.5 Hole Section / o eration: Drillin 6 %8" production interval. T e Densit LSRV PV YP MBT API FL H Flo-ProSF 8.5 - 8.6 >20,000 7 - 12 20 - 28 <3 4 - 6 9.0 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade ~ Connection ~ Length Top and / tvd Bottom. and / tvd 8'/z" 7" 26.0# L-80 BTC-M 5,377' 5,000' / 4,328' 10,377' / 8,832' 8.681" 7" 26.0# L-80 TC-II 5,000' Surface 5,000' / 4,328' 6 %8" 4'/z" 12.6# L-80 IBT-M 2,097' 10,227'/ 8,721' 12,324' / 9,067' Tubin 4'/z" 12.6# L-80 TC-II 10,227' Surface 10,227' / 8,721' W-17A Sidetrack Page 2 • Cementing Program • Casin Strin 7", 26.0#, L-80, BTC-M Intermediate Casin drillin liner Slurry Design Basis: Lead slurry. 4,077' of 7" X 8'/z" annulus with 40% excess, plus 300' o 5/s" liner lap, plus 150' of 4" drill pipe X 9 5/s" annulus. Lead TOC to ~ ,000' d (liner top packer). Tail slurry. 1,000' of 7" X 8 Y2" annulus with 40% excess, plus ~86' of 7", 26.0# shoe tract. Tail TOC to ~9,377'md. Pre-Flush: None planned S acer Fluid: 35.Obbls MudPUSH II at 11.90pp Slur T e 12.0 LiteCRETE Mix method Mix-On-The-FI Lead Slurry: BHST /BHCT 150° F / 120° F Thickenin time TBD hrs TBD min Slur Volume 145.Obbl / 814cf 35 x LiteCRETE, 12.0 .3 f/sk. Slur T e 15.8 Class `G finer slur with `GASBLO ditive Mix method Batch mix Tail Slurry: BHST /BHCT 150° F / 120° F Thickenin time 4 hrs 00 min Slur Volume 35.Obbl / 197cf / 68 x Class `G', 15.8 .17 /sk. c.X w Casin Strin 7", 26.0#, L-80, TC-II Tie Back liner Slurry Design Basis: Lead slurry. None planned. Tail slurry. 1,650' of 7" X 9 5/s" annulus, plus ~45' of 7", 26.0# shoe tract. Tail TOC to ~3,350'md. Pre-Flush: Fresh water S acer Fluid: 35.Obbls MudPUSH II at 9.6pp Slur T e None tanned Mix method N/A Lead Slurry: BHST /BHCT N/A Thickenin time N/A Slur Volume None tanned. Slur T e 15.8 Class `G' liner slur Mix method Batch mix Tail Slurry: BHST /BHCT 150° F / 120° F Thickenin time 4 hrs 00 min `~` ~~` Slur Volume 42.Obbls / 237cf 27 sx Class `G', 15.8 ; 1.1 f/sk. W-17A Sidetrack Page 3 • Casin Strin 4'/z", 12.6#, L-80, IBT-M Production liner Slurr Desi n Basis: y g Lead slurry. None planned. Tail slurry. 1,947' of 4'/z" X 6 %"" annulus with 40% excess, plus 150' of 4 '/z" X 7" liner lap, plus 200' of 4" dr' Ip X 7" annulus, plus ~86' of 4'/z", 12.6#, shoe tract. Tail TOC to ~ ,2 md'. Pre-Flush: 15.Obbls CW 100 S acer Fluid: 30.Obbls MudPUSH II at 9.6pp Slur T e None tanned Mix method N/A Lead Slurry: BHST /BHCT N/A Thickenin time NIA Slur Volume N/A Slur T e 15.8 Class `G' liner slur with `GASBLOK' additive Mix method Batch mix Tail Slurry: BHST /BHCT 150°F / 120° F Thickenin time 4 hrs 00 min Slurry Volume 55.Obbl / 309c 26 x Class `G', 15.8ppg; .17 sk. Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9 5/8" casin Cement plug to surface 30 min recorded 3,500psi surface 9 5/e" milled section 20' new formation beyond window FIT 12.5ppg EMW 7" drillin liner /tieback liner Float a ui ment to surface 30 min recorded 4,000 si surface 7" liner shoe 20' new formation be and shoe FIT 10.0 EMW 4'/z" roduction liner Float a ui ment to surface 30 min recorded 4,000 si surface Well Control Well control equipment consisting of 5,000psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8'/z" intermediate interval Maximum antici ated BHP: 3,380psi at 8,750' sstvd. Maximum surface ressure: 2 5 Si (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: 31 bbls with 11.4 W FIT, 180.Obbls with 12.5 EMW FIT Planned BOPE test pressure: ms : 250psi low / 4, 0 si high ; Annular : 250psi low / 2,500psi high 7 da test c cle R hase); 14 da test c cle Drillin hase ~ BOPE configuration for 7" Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams. drilling liner. The rig will follow the current, best practice of picking up a joint of drill pipe, crossed over to casing thread, in the event of a kick. This configuration provides two sets of employable rams, rather than one. Similarly, the rig will not change to 7" rams in preparation for running the tieback liner. W-17A Sidetrack Page 4 Well Interval: 6 %e" production interval Maximum antici ated BHP: 3,400psi at 8,800' sstvd. Maximum surface ressure: 2,520 SI (based upon BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 10.Opp E Planned BOPE test pressure: Rams : 250psi low / ,000p 'high ; Annular : 250psi low / 2,500psi high 14 da test c cle hase Planned com letion fluid: 8.4 seawater / 7.1 pp Diesel Disposal Annular In'ection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 j for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. Geologic Prognosis Formation MD TVDbkb TVDss Comments UGMa -4,525 OA -4,920 OBd -5,095 OBf -5,210 Fault 1 -5,600 CM2 -5,600 CM 1 -6,170 HRZ -6,650 TKup / LCU -6,900 Fault 2 -7,320 TKNG -7,420 TJ F -7,760 THE -7,980 TJD -8,205 TJB -8,590 TJA -8,655 TSGR -8,750 TSHA -8,770 Estimated Pore ressure 3,384 si 7.4 EMW TSHB -8,820 Estimated Pore ressure 3,400 si 7.4 EMW TSHC -8,840 Estimated Pore ressure 3,407 si 7.4 EMW TEIL -8,850 Estimated Pore ressure 3,411 si 7.4 EMW TSAD - 46P -8,860 Estimated Pore ressure 3,414 si 7.4 EMW 45P -8,900 Estimated Pore ressure 3,428 si 7.4 EMW 44P -8,940 Invert oint -8,960 Estimated Pore ressure 3,449 si 7.4 EMW 44P -8,940 45P -8,900 Estimated Pore ressure 3,428 si 7.4 EMW TSAD - 46P -8,870 Not enetrated 45P -8,900 44P -8,940 OWC -8,970 TD in 44P -8,985 W-17A Sidetrack Page 5 • • TD Criteria TD Criteria: I Geo-steer as directed to cross-cut from the 46P through the 44P. TD the well according. to the directional plan. Fault Prognosis Fault Formation MD TVDss Estimated Direction of Uncertainty Encountered Intersect Intersect Throw Throw Fault #1 U er Colville 6,568' -5,600' ~85' West +/- 100' Fault #2 Lower Miluveach 8,427' -7,320' ~40' D to the W +/- 50' Operations Summary Pre-Rig Operations: 1. The 3'h", 9.2#, L-80, EUE 8rnd tubing may be corroded. Indications are that the tubing has leaks from 2,250' to ~2,700'md. 2. R/U slick-line. RIH and retrieve the Tubing Tail Plug from the `X' landing nipple at 11,162'md. POOH. 3. R/U coiled tubing. RIH and plug and abandon the open perforations (~93') with 15.8ppg class `G' cement. The estimated cement volume required is 40.Obbls, minimally. This is based upon 195' 3 '/z", 9.2# tubing, 737' of 7", 26.0# liner and ~10.Obbls of slurry to squeeze the open perforations. Leave top of cement -- 11,000'. POOH. 4. Drift the 3'h", 9.2#, L-80 tubing to tag TOC at ~11,000'md. 5. R/U SWS E-line. RIH with the appropriate chemical cutter and cut the 3'h" tubing at 7,800'md. 6. Attempt to circulate the well to seawater through the tubing cut, until returns are clean. If there are holes in the tubing, as suspected, it may be difficult to get a complete circulation. 7. Attempt a CMIT T X IA to 3,500psi for 30 minutes. The last attempted CMIT failed, but the failure point could not be positively identified. 8. Attempt an MIT-OA to 1,500psi. 9. Bleed casing and annulus pressures to zero. Freeze protect to 2,200' MD with diesel. 10. Function all tubing and casing Lock Down Screws. A PPPOT-T to 5,000psi and a PPPOT-IC to 3,800psi both passed on 7/16/2005. All LDS were functioned and were good. 11. Set a BPV. Remove well house and flow line. Level the pad as necessary. Rig Operations: 1. MI / RU Nabors 7ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. Install TWC. 3. Nipple down the tree. Nipple up and test BOPE to 4,000psi. Pull TWC. 4. R/U. Pull the 3 '/z" tubing from the tubing cut at ~7,800'md and above. Be prepared to spool up the Otis SSSV control lines. 5. M/U an 8 1/2" mills assembly. RIH and drift the 9 5/8" casing to the tubing stub. 6. Circulate the well to seawater until returns are clean. POOH. 7. R/U and pressure test the 9 5/8" casing to 3,500psi. 8. If the casing test fails, be prepared to P/U a HES 9 5/8" RTTS. RIH and locate the leak point. POOH. 9. !U SW E-line. M/U and RIH to tubing stub with USIT. Log to above the top of the Schrader at approximately 5,350'md. Confirm top of cement in 9 5/8" casing annulus. 10. M/U a HES 9 5/8" Cast Iron bridge plug. RIH and set the CIBP at ~5,575'md. POOH. .~~ 11. M/U a 9 5/8" Section Milling assembly, per Baker representative. ~s iQ ~~ ~~" 12. RIH to the CIBP. Displace the well to the 9.Oppg milling fluid. Spot an 18.Oppg mud pill from the CIBP ~ry,pV~, [ , up 200 feet. a W-17A Sidetrack Page 6 • • 13. Begin the 9 5/8" casing cut at ~5,250'md. Mill 125' of 9 5/8" casing to ~5,375'md. Trip as required for% section milling assembly. Pump sweeps as detailed in the `Section Milling' RP, minimally. 14. Circulate the hole clean, POOH and UD the section milling assembly. Flush the BOPE stack. 15. M/U a 500' - 3 ~/2" cementing stinger with a "mule shoe". RIH to ~5,225'md. Wash down slowly to ~5,475'md. Circulate and condition the mud until clean. 16. Pump 50bbls class `G' 17.Oppg cement kickoff plug. Displace and spot a balanced plug. ° 17. Slowly pull out of the cement plug until the stinger is above the top of the cement. 18. Close the annular preventer and perform a hesitation squeeze. Hold final pressure at least one hour. Open annular and POOH. UD stinger. ? i..tGe~- 20. M/U a clean out assembly with an 8'h" mill tooth bit. RIH and dress the cement to the top of the milled section, at ~5,250'md. ~ 21. Circulate and displace the well to clean 9.Oppg LSND drilling fluid. POOH. 22. M/U an 8'/z" Dir/GR/Res/PWD assembly. RIH to the top of kick off plug. 23. Kick off of the cement plug, per directional program. Drill approximately 20 feet of new formation. 24. Circulate the well clean. Pull into the 9 5/8" casing and attempt an FIT to 12.5ppg EMW. 25. Drill ahead, according to the directional program, to section TD at the top of the Sag River formation. Circulate and condition the hole. POOH. f 26. Run and cement the 7" intermediate drilling liner, per program. 27. R/U and run a 7", 26#, L-80 tieback liner to surface. 28. Sting into drilling liner tie back receptacle and confirm seal integrity. 29. Pull out of the tie back receptacle and circulate the annulus to adequate freeze protection fluid. 30. Set the tieback liner in the tieback receptacle to bury the seal assembly. Confirm seal integrity. 31. N/D and lift the BOPE stack. Set the 7" tieback liner in slips, with tension, per the Cameron representative. 32. Cut the 7" tieback liner. Set back the BOPE stack. 33. Install slips seal. N/U a new tubing spool, with secondary pack-off installed. Test the pack-off per Cameron representative. 34. N/U the BOPE and test. 35. M/U a simple 6 1/8" cleanout rotary assembly with a tri-cone bit. RIH to the drilling liner landing collar. 36. Test the 7" intermediate casing to 4,OOOpsi for 30 minutes. Record the test. 37. Drill out the landing collar, cement, and float equipment to the liner shoe. 38. Displace the well to 8.5ppg Flo-Pro drilling fluid. POOH, UD cleanout assembly. 39. R/U SWS E-line. M/U and RIH to the 7" shoe with a USIT. Log the 7" liner to the liner top at ,/ approximately 5,000'md. Confirm adequate zonal isolation across the 7" annulus, as required for injection service. POOH and R/D SWS. 40. M/U a 6 1/8" Dir/GR/Res directional assembly. RIH to the shoe. /~ 41. Drill out the shoe plus ~20 feet of new formation. Conduct an FIT to 10.Oppg EMW. 42. Drill ahead, per directional proposal, to the end of the high dogleg section at --10,550'md. POOH for horizontal BHA. 43. M/U the horizontal directional assembly. 44. RIH and drill the horizontal interval, per directional program and requirement, to section TD. 45. Circulate and condition the hole in preparation for running 4 1/2", 12.6#, L-80, IBT-M liner. POOH. 46. Run and cement the 4'h" production liner, extending the liner lap 150' into the 7" liner shoe. POOH. 47. R/U and test the casing X liner to 4,OOOpsi for 30 minutes. Record the test. 48. P/U and RIH with Schlumberger 2 7/8" DPC perforating guns. Perforate the production intervals, per subsurface team. POOH. 49. R/U and run a 4 1/2", 12.6#, L-80, TC-II completion, stinging into the 4 1/2" liner tie back sleeve. 50. Space and land the completion. RILDS. 51. Circulate the annulus to seawater with Corrosion Inhibitor. 52. Drop the ball /rod. Set the packer and individually test the tubing and annulus to 4,OOOpsi for 30 minutes. Record each test. 53. Install a TWC. 54. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. Pull the TWC. 55. Freeze protect the well to 2,200'. Allow the diesel freeze protection fluid to U-tube to equilibrium. ~ 56. Install a BPV. Secure the well. 57. Rig down and move off. W-17A Sidetrack Page 7 • ~ Post-Riq Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Re-install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: 08/01/05 Estimated Spud Date: 08/25/05 Phase 1: Move In /Riq Up /Test ROPE Planned Phase Time Planned Phase Cost 22 hours $57,421 Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards - No wells will require shut-in for the rig move onto W-17. However, W-18 is 35.0' to the North, and W-16 is 35.0' to the South. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. - During MI/RU operations, the W-17 well bore will be secured with the following barriers: o Tubing: the P&A cement plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - Prior to pulling the tree, verify there is a static column of kill weight fluid to surface and that no pressure exists. - During ND/NU BOPE operations, the W-17 well bore will be secured with the following barriers: o Tubing: the P&A cement plug, kill weight fluid, and a TWC. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - W--pad is not designated as an H2S site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading W-18 20ppm W-15A 25ppm W-16 10ppm W-21A 15ppm i The maximum level recorded of H2S on the pad was 5 m, in 2005. i - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud W-17A Sidetrack Page 8 Phase 2: De-complete Well • Planned Phase Time Planned Phase Cost 51 hours $186,303 Reference RP • "De-completions" RP Issues and Potential Hazards - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. - Have all wellhead and completion equipment NORM-tested, following retrieval. - Note that this wellhead is McEvoy SSH. The tubing hanger is McEvoy (5) seal 13" X 3'/z" TDS top thread and bottom thread with a 3.030 type `H' BPV profile. Once the stack has been nippled down, verify the hanger thread and type in preparation for de-completion. - There is a 3'/z" Otis `XDB' SSSV landing nipple with dual ~/a" control lines. There were 32 control line protectors, (1 every other joint) and 4 stainless steel bands (2 at the BVN and 2 at the hanger) used in securing the EUE 8rd tubing will be chemical cut at ~7,800'md. - The 3'/2", 9.2#, L-80, EUE 8rd tubing may be corroded from ~2,250'md to ~2,700'md, based upon a caliper surrey run February 15, 1999. An LDL indicated possible tubing leaks through this range. Phase 4: Section Mill Planned Phase Time Planned Phase Cost 131 hours $580,717 Reference RP • "Section Milling to Sidetrack a Well" RP Issues and Potential Hazards - There is likely no cement behind the 9 5/" casing at the section mill point. - Ensure that the well has been fully displaced to the milling fluid, as prescribed by MIDF, prior to beginning section milling operations. - Once section milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled. W-17A Sidetrack Page 9 ~ • Phase 5: Drill 8 1/2" Intermediate Hole Interval Planned Phase Time Planned Phase Cost 122 hours $507,330 Reference RP • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards - This well bore will exit the original well into the Ugnu. This well bore will drill the Schrader, Colville, HRZ and the Kingak, to the top of the Sag River formation. Previous W-pad wells drilled the Kingak with 9.8 to 10.6ppg mud weights. For this well, the HRZ will require a mud weight of 9.8ppg to 10.2ppg. The Kingak shale will require a mud weight of 10.9ppg. Maintain mud weight / at 10.9ppg, minimally, from above the Kingak to the 7" casing point. Follow all shale drilling practices to minimize potential problems. - Two fault crossings are anticipated in drilling this intermediate section. The first fault will likely be encountered in the upper Colville, at approximately 6,568'md. The second fault will be crossed in the Miluveach, at approximately 8,425'md. Neither of these faults is expected to create a lost circulation hazard. There were no fault related losses associated with the drilling of the original W- 17well. - KICK TOLERANCE: In the worst-case scenario of 8.6ppg pore pressure at the Sag River depth, a fracture gradie of 11.4ppg at the milled section window, and 10.9ppg mud in the hole, the kick tolerance is ~ 31. bls. With a fracture gradient of 12.5ppg at the milled section window, the kick tolerance i O.Obbls. Phase 6: Run and Cement 7" Intermediate Liner Planned Phase Time Planned Phase Cost 40 hours $554,916 Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Freeze Protecting an Outer Annulus" RP • "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab /surge pressures could initiate Kingak instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. - Ensure that a TIW valve with a cross over to 7" BTC casing is on the rig floor before running the drilling liner. - If a 7" tieback liner is run, it will be necessary to freeze protect the 7" X 9 5/8" annulus, prior to setting the tieback liner in slips. W-17A Sidetrack Page 10 • • Phase 7: Drill 6 1/8" Production Hole Interval Planned Phase Time Planned Phase Cost 142 hours $771,202 Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards - The parent well, W-17, experienced no lost circulation events during drilling operations. - There were no significant lost circulation events in drilling nearby surrounding wells. - The planned well, W-17A, is not expected to cross any faults while drilling the production interval. Phase 9: Run 4 ~/2" Production Liner Planned Phase Time Planned Phase Cost 32 hours $233,688 Reference RP •3 "Modified Conventional Liner Cementing" RP Issues and Potential Hazards - The completion design is to run a 4 ~h", 12.6#, L-80, IBT-M solid liner throughout the production interval. - Differential sticking is possible. The 8.6ppg Flo-Pro will be ~500psi over balanced to the Ivishak Zone 4 formation. Minimize the time the pipe is left stationary while running the liner. - Sufficient 4'h" liner will be run to extend 150' back up into the 7" liner. - Ensure the 4 ~/z" liner top packer is set prior to POOH. Phase 10: DPC Perforate Planned Phase Time Planned Phase Cost 37 hours $329,317 Reference RP • "Drill Pipe Conveyed Perforating" RP Issues and Potential Hazards - Approximately 1,000' of 2'/8' `Powerjet' TCP guns, at 4 spf, are planned. - The well will be DPC perforated, ~500psi overbalanced, after running the 4'/z" liner. Ensure all personnel are well briefed on Schlumberger's perforating procedures and that all responsibilities W-17A Sidetrack Page 11 ~ • are understood. Only essential personnel should be present on the rig floor while making up DPC guns. - Expect to lose fluid to the formation after perforating. Have ample seawater on location and be prepared with LCM if necessary. Phase 12: Run 4 ~/2" L-80 Completion Planned Phase Time Planned Phase Cost 26 hours $541,865 Reference RP • "Completion Design and Running" RP • "Tubing connections" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. - The completion, as designed, will be to run a 4~h", 12.6#, L-80, TC-II production tubing string, stinging into the 4'h" liner tieback sleeve. Phase 13: ND/NU/Release Rig Planned Phase Time Planned Phase Cost 18 hours $58,481 Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - During ND BOPE / NU adapter /tree operations, the W-17A well bore will be secured with the following barriers: o Tubing: TWC and kill weight fluid above ball/rod. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - During RD/MO operations, the W-17A well bore will be secured with the following barriers: o Tubing: Tree, a BPV and kill weight fluid above ball/rod. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - No wells will require shut-in for the rig move off of W-17A. However, W-18 is 35.0' to the North, and W-16 is 35.0' to the South. These are the closest neighboring wells. Care should be taken while moving off of the well. Spotters should be employed at all times. W-17A Sidetrack Page 12 .Schlumberger ~ ~ h~ ALL W-17A (P4) FIELD Prudhoe Bay Unit - WOA STRDI:IDRE W-PAD M1laAnelic Parameters ~ , ca Lnrstio NAD2] as .. is Planes. Zane 04.115 Faal Miscellaneous Modal. BGGM ]005 Dlp: B08J5" Date: JuN 9. 2005 Lal^s N]0 t]51]]6 NnrtMng 9490 fa I1l1Sa Grq Conv: •0 B54J 1046" Slot W-t] NOReI Rotary Table l612]Rabove MSLI Mag Dec. •24641' FS 5]5822ni Lnn Wtd95JJ 219 E.asti,g 532049.0] ttIS Scale Fad 09999td2622 W~t ]q lPd1~5J00A KOP Srvy Dale. J ly t9, 2005 2400 3200 4000 4800 5600 6400 7200 4000 4800 5600 0 0 w 6400 m U 7200 8000 8800 4000 4800 5600 6400 7200 8000 8800 2400 3200 4000 4800 5600 6400 7200 Vertical Section (ft) Azim = 98.94°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-W ~~ Schlumberger ~ WEL~ W_17A (P4) `I`LD Prudhoe Bay Unit - WOA STRUCTURE W-PAD Magneuc Parameters SuMa~a LOraYOn w.D2/nlaska SWe PWnes. Zone 0.1. U5 Fnel ALauJbnwus MoCet. BGGM 2005 Ory BO B36' Gale ~, Lal. N]01]63 ]]6 n6lny. 5959690.Oa IIUS GnO Conv: bB5n3t Wfi' Slw. NDReI. RWary Tads 1B11]flaDOVe MSLI Atay Dec. •2a.&1' FS 2nT Wn. W1a963B2]9 Easlirg 8120J9.03 M1US Stale Fatl: 099991a2622 Plan W~~]A 1P.1~5300fl KOP 6rvy Dale: 1uty 19. 3005 1500 750 n n n Z 0 C_ _ 0 II N f0 U V V -750 250 3000 3750 4500 5250 6000 6750 1500 750 0 -750 •i 250 3000 3750 4500 5250 6000 6750 «< ~l~l Scale = 1(in):750(ft) E »> W-17A P4 Pr o ~ Schlumberger ( ) oa sa Report Date: Jufy 19, 2005 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure I Slot: W-PAD / W-17 ~1 ~;' ~~ Well: W-17 ~~~ Borehole: Plan W-17A UW IIAPI#: 500292186501 Survey Name 1 Date: W-17A (P4) - 5300 ft KOP /July 19, 2005 Tort I AHD I DDI I ERD ratio: 202.872° / 6661.80 ft / 6.264 / 0.735 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 7017 53.776, W 149 5 33.279 Location Grid NIE YIX: N 5959490.040 ftUS, E 612049.030 ftUS Grid Convergence Angle: +0.85431046° Survey 1 DLS Computation Method: Minimum Curvature / Lul Vertical Section Azimuth: 98.940° y Vertical Section Origin: N 0.000 ft, E 0.000 ft ND Reference Datum: Rotary Table TVD Reference Elevation: 81.3 ft relative to MSL Sea Bed I Ground Level Elevation: 47.830 ft relative to MSL Magnetic Declination: 24.641 ° Total Field Strength: 57582.156 nT Magnetic Dip: 80.835° Declination Date: July 19, 2005 Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corr Mag North •> True North: +24.641° Measured Vertical Along Hole Comments Inclination Azimuth SulrSea ND ND NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Departure K d de tt ft ft ft it ft de 1100 ft de de 1100 ft de 1100 k ftUS ttUS i ie-in survey bZ/3.L/ 44.7 / 8/.LS 444lA~J 4bZt5.L5b ZIbZ.`JU LZl`J.Zb 7tSZ.tSb ZZU25.74 U.`Jb 7L.bLli U.`JL V.J/ J`JJ`J/U5./y bl4Lb4.U"i N !U "I / bb.b/Z VV 74`J 4 YS.yUy KOP Crv 4/100 5300.00 44.42 87.31 4466.72 4547.99 2171.18 2237.92 183.75 2226.79 0.96 174.51 G 0.94 0.30 5959706.96 614272.63 N 70 17 55.580 W 149 4 28.366 5400.00 40.44 87.90 4540.52 4621.79 2237.32 2305.38 186.59 2294.18 4.00 174.07G -3.98 0.59 5959710.79 614339.97 N 70 17 55.608 W 149 4 26.401 5500.00 36.46 88.59 4618.81 4700.08 2298.40 2367.55 188.50 2356.32 4.00 173.53G -3.98 0.69 5959713.64 614402.07 N 70 17 55.627 W 149 4 24.589 5600.00 32.49 89.43 4701.23 4782.50 2354.15 2424.15 189.50 2412.91 4.00 172.83G -3.97 0.84 5959715.47 614458.64 N 70 17 55.636 W 149 4 22.940 5700.00 28.53 90.48 4787.37 4868.64 2404.28 2474.90 189.56 2463.67 4.00 171.93G -3.96 1.04 5959716.30 614509.38 N 70 17 55.637 W 149 4 21.460 5800.00 24.57 91.83 4876.81 4958.08 2448.55 2519.59 188.70 2508.34 4.00 170.73G -3.95 1.35 5959716.10 614554.06 N 70 17 55.628 W 149 4 20.158 5900.00 20.63 93.65 4969.11 5050.38 2486.74 2558.01 186.92 2546.72 4.00 169.04G -3.94 1.83 5959714.89 614592.46 N 70 17 55.610 W 149 4 19.039 End Crv 5934.48 19.28 94.45 5001.52 5082.79 2498.46 2569.78 186.09 2558.46 4.00 O.OOG -3.92 2.30 5959714.23 614604.21 N 70 17 55.602 W 149 4 18.697 OBf 6144.75 19.28 94.45 5200.00 5281.27 2567.68 2639.22 180.70 2627.69 0.00 O.OOG 0.00 0.00 5959709.88 614673.50 N 70 17 55.549 W 149 4 16.679 CM2 6568.52 19.28 94.45 5600.00 5681.27 2707.19 2779.15 169.85 2767.20 0.00 O.OOG 0.00 0.00 5959701.11 614813.15 N 70 17 55.442 W 149 4 12.612 CM1 7172.40 19.28 94.45 6170.00 6251.27 2905.98 2978.55 154.38 2966.00 0.00 O.OOG 0.00 0.00 5959688.61 615012.14 N 70 17 55.289 W 149 4 6.817 HRZ 7702.11 19.28 94.45 6670.00 6751.27 3080.36 3153.47 140.81 3140.39 0.00 O.OOG 0.00 0.00 5959677.64 615186.70 N 70 17 55.155 W 149 4 1.733 Kuparuk 7935.18 19.28 94.45 6890.00 6971.27 3157.08 3230.43 134.84 3217.12 0.00 O.OOG 0.00 0.00 5959672.82 615263.50 N 70 17 55.096 W 149 3 Crv 4/100 7953.92 19.28 94.45 6907.69 6988.96 3163.25 3236.62 134.36 3223.29 0.00 0.93G 0.00 0.00 5959672.43 615269.68 N 70 17 55.091 W 149 3 8000.00 21.12 94.53 6950.93 7032.20 3179.12 3252.53 133.11 3239.15 4.00 0.86G 4.00 0.18 5959671.42 615285.56 N 70 17 55.079 W 149 3 58.855 81 D0.00 25.12 94.67 7042.88 7124.15 3218.27 3291.80 129.96 3278.29 4.00 0.73G 4.00 0.14 5959668.85 615324.73 N 70 17 55.047 W 149 3 57.714 8200.00 29.12 94.78 7131.86 7213.13 3263.73 3337.38 126.20 3323.72 4.00 0.63G 4.00 0.10 5959665.77 615370.21 N 70 17 55.010 W 149 3 56.389 8300.00 33.12 94.86 7217.45 7298.72 3315.27 3389.06 121.86 3375.21 4.00 0.56G 4.00 0.08 5959662.20 615421.76 N 70 17 54.967 W 149 3 54.888 8400.00 37.12 94.92 7299.22 7380.49 3372.65 3446.58 116.95 3432.53 4.00 0.51 G 4.00 0.07 5959658.15 615479.13 N 70 17 54.919 W 149 3 53.218 8500.00 41.12 94.98 7376.79 7458.06 3435.59 3509.67 111.51 3495.38 4.00 0.47G 4.00 0.05 5959653.64 615542.05 N 70 17 54.865 W 149 3 51.386 Fault 1 8504.27 41.29 94.98 7380.00 7461.27 3438.39 3512.48 111.26 3498.18 4.00 0.47G 4.00 0.05 5959653.44 615544.86 N 70 17 54.863 W 149 3 51.304 End Crv 8546.92 43.00 95.00 7411.62 7492.89 3466.94 3541.10 108.78 3526.69 4.00 O.OOG 4.00 0.05 5959651.37 615573.40 N 70 17 54.838 W 149 3 50.473 Top Kingak 8558.38 43.00 95.00 7420.00 7501.27 3474.74 3548.91 108.09 3534.47 0.00 O.OOG 0.00 0.00 5959650.81 615581.19 N 70 17 54.831 W 149 3 50.246 Top Sag 10265.82 43.00 95.00 8668.74 8750.01 4636.46 4713.38 6.60 4694.51 0.00 O.OOG 0.00 0.00 5959566.63 616742.51 N 70 17 53.827 W 149 3 16.432 WeIlDesign Ver SP 1.0 Bld(doc40x_56) W-17\W-17\Plan W-17A\W-17A (P4) - 5300 ft KOP Generated 7/19/2005 10:53 AM Page 1 of 2 10376.92 43.00 95.00 8750.00 8831.27 4712.05 4789.16 0.00 4770.00 0.00 O.OOG 0.00 0.00 5959561.15 616818.08 N 70 17 53.761 W 149 3 14.231 7" Csg Pt 10376.94 43.00 95.00 8750.01 8831.28 4712.06 4789.17 0.00 4770.01 0.00 O.OOG 0.00 0.00 5959561.15 616818.09 N 70 17 53.761 W 149 3 14.231 Top Sag 10376.95 43.00 95.00 8750.02 8831.29 4712.07 4789.18 0.00 4770.02 0.00 O.OOG 0.00 0.00 5959561.15 616818.10 N 70 17 53.761 W 149 3 14.231 Crv 20!100 10397.92 43.00 95.00 8765.36 8846.63 4726.34 4803.48 -1.25 4784.27 0.00 24.07G 0.00 0.00 5959560.12 616832.36 N 70 17 53.749 W 149 3 13.815 10400.00 43.38 95.25 8766.87 8848.14 4727.76 4804.90 -1.38 4785.68 20.00 23.89G 18.27 11.88 5959560.01 616833.78 N 70 17 53.748 W 149 3 13.774 Shublik 10404.33 44.17 95.75 8770.00 8851.27 4730.75 4807.90 -1.66 4788.67 20.00 23.53G 18.31 11.63 5959559.77 616836.77 N 70 17 53.745 W 149 3 13.687 10500.00 62.08 104.27 8827.24 8908.51 4806.82 4884.07 -15.55 4863.49 20.00 18.35G 18.72 8.90 5959547.00 616911.78 N 70 17 53.608 W 149 3 11.506 End Crv 10531.71 68.12 106.42 8840.59 8921.86 4835.39 4912.82 -23.17 4891.21 20.00 O.OOG 19.03 6.77 5959539.80 616939.62 N 70 17 53.533 W 149 3 10.698 TSAD 10583.81 68.12 106.42 8860.00 8941.27 4883.32 4961.16 -36.83 4937.58 0.00 O.OOG 0.00 0.00 5959526.83 616986.18 N 70 17 53.398 W 149 3 9.347 Crv 10/100 10595.50 68.12 106.42 8864.36 8945.63 4894.08 4972.01 -39.89 4947.99 0.00 102.53G 0.00 0.00 5959523.92 616996.63 N 70 17 53.368 W 149 3 9.044 10600.00 68.02 106.89 8866.04 8947.31 4898.22 4976.18 -41.09 4951.99 10.00 102.35G -2.15 10.53 5959522.79 617000.65 N 70 17 53.356 W 149 3 8.927 Tgt 1 10610.53 67.80 108.00 8870.00 8951.27 4907.87 4985.94 -44.02 4961.30 10.00 96.98G -2.10 10.55 5959520.00 617010.00 N 70 17 53.327 W 149 3 8.656 End Crv 10654.03 67.34 112.68 8886.60 8967.87 4947.27 5026.14 -57.98 4998.98 10.00 O.OOG -1.06 10.76 5959506.60 617047.89 N 70 17 53.190 W 149 3 7.557 Crv 10/100 10755.67 67.34 112.68 8925.76 9007.03 5038.38 5119.94 -94.15 5085.53 0.00 -0.46G 0.00 0.00 5959471.73 617134.95 N 70 17 52.833 W 149 3 5.035 10800.00 71.77 112.64 8941.25 9022.52 5078.72 5161.47 -110.15 5123.85 10.00 -0.45G 10.00 -0.09 5959456.31 617173.50 N 70 17 52.676 W 149 3 10900.00 81.77 112.56 8964.10 9045.37 5173.19 5258.69 -147.51 5213.61 10.00 -0.43G 10.00 -0.08 5959420.29 617263.80 N 70 17 52.308 W 149 3 Tgt 2 10982.29 90.00 112.50 8970.00 9051.27 5252.90 5340.70 -178.93 5289.35 10.00 O.OOG 10.00 -0.08 5959390.00 617340.00 N 70 17 51.998 W 149 2 59.096 11000.00 91.77 112.51 8969.73 9051.00 5270.12 5358.40 -185.71 5305.71 10.00 O.OOG 10.00 0.06 5959383.47 617356.46 N 70 17 51.931 W 149 2 58.619 11100,00 101.77 112.57 8957.95 9039.22 5366.51 5457.58 -223.73 5397.31 10.00 O.OOG 10.00 0.06 5959346.82 617448.61 N 70 17 51.557 W 149 2 55.950 End Crv 11126.55 104,43 112.58 8951.93 9033.20 5391.65 5483.44 -233.66 5421.19 10.00 O.OOG 10.00 0.06 5959337.25 617472.63 N 70 17 51.459 W 149 2 55.254 Crv 10/100 11371.63 104.43 112.58 8890,88 8972.15 5622.30 5720.79 -324.81 5640.34 0.00 -149.39G 0.00 0.00 5959249.38 617693.09 N 70 17 50.561 W 149 2 48.868 11400.00 101.98 111.11 8884.40 8965.67 5649.21 5748.41 -335.08 5665.97 10.00 -149.73G -8.62 -5.20 5959239.49 617718.87 N 70 17 50.460 W 149 2 48.121 11500.00 93.31 106.08 8871.10 8952.37 5746.80 5847.42 -366.60 5759.81 10.00 -150.40G -8.67 -5.03 5959209.38 617813.16 N 70 17 50.149 W 149 2 45.386 Tgt 3 11538.05 90.00 104.20 8870.00 8951.27 5784.60 5885.45 -376.53 5796.51 10.00 -150.16G -8.70 -4.94 5959200.00 617850.00 N 70 17 50.051 W 149 244.317 11600.00 84.63 101.11 8872.90 8954.17 5846.33 5947.31 -390.09 5856.86 10.00 -150.02G -8.67 -4.99 5959187.35 617910.54 N 70 17 49.917 W 149 2 42.558 End Crv 11642.97 80.91 98.93 8878.31 8959.58 5888.95 5989.94 -397.51 5898.83 10.00 O.OOG -8.65 -5.06 5959180.55 617952.62 N 70 17 49.844 W 149 2 41.334 Tgt 4 12223.39 80.91 98.93 8970.00 9051.27 6462.07 6563.06 -486.52 6465.00 0.00 O.OOG 0.00 0.00 5959100.00 618520.00 N 70 17 48.964 W 149 2 24.834 TD / 4-1/2" ln r 12323.39 80.91 98.93 8985.80 9067.07 6560.81 6661.80 -501.86 6562.55 0.00 O.OOG 0.00 0.00 5959086.12 618617.76 N 70 17 48.812 W 149 2 21.991 Leaal Descri ption: Northing (Yl fftUSl Eastina (X) fftUSl Surface : 4513 FSL 1183 FEL S21 T11N R12E UM 5959490.04 612049.03 Tgt 1 : 4511 FSL 1693 4467 FSL 1501 FEL 822 FEL S22 T11N R12E T11N R12E UM UM 5959561.15 5959520.00 616818.08 617010.00 Tgt 2 : 4332 FSL 1174 FEL S22 T11 N R12E UM 5959390.00 617340.00 Tgt 3 : 4134 FSL 667 FEL S22 T11 N R12E UM 5959200.00 617850.00 Tgt 4 : 4024 FSL 5279 FEL S23 T11 N R12E UM 5959100.00 618520.00 BHL : 4008 FSL 5181 FEL S23 T11N R12E UM 5959086.12 618617.76 WeIlDesign Ver SP 1.0 Bld(dorAOx_56) W-17\W-17\Plan W-17A\W-17A (P4) - 5300 ft KOP Generated 7!19!2005 10:53 AM Page 2 of 2 Schlumber er g Anticollision Report Company: BP Amoco Date:. 7/19/2005 Time: 09:44:41 Page.:. 1 Field: Prudhoe Bay Reference Site:. PB W Pad Co-ordinate(NE) Reference: Welf: W-17, True North- Reference Well: W-17 Vertical (TVD) Reference: ' W-17A Plan 81.3 12efereoce WellpatlPJan W-17A Db: Oracle GLOBAL SCAN APPLIED: Ail wellpaths within 200'+ 100/1000 of reference - TRefenmec'FIGHT ~IRcipakRiarf~lBLANNED PROGRAM Interpolation MethodMD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 5300.00 to 12323.39 ft Scan Method: Trav Cylinder North Maximum Radius3000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 7/15!2005 Validated: No Version: 6 Planned From To Survey Toolcode Tool Name ft ft 38.17 5273.27 1 : Schlumberger GCT multishot (38.17-118~CSE~1~ Schlumberger GCT multishot 5273.27 12323.39 Planned: Plan #4 V1 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole-Size Name ft #t in in 2844.67 2679.12 13.375 17.500 13 3/8" 5100.00 4402.84 9.625 12.250 9 5/8" 10378.29 8832.27 7.000 8.500 7" 12303.71 9063.96 4.500 6.125 4 1 /2" Summary <- --------------- ---- Offset Wellpath ---------- -----------> Site Well Wellpath PB W Pad Plan W-213 Plan W-213 V3 Plan: W- PB WPad Plan W-214 Plan W-214i V4 Plan: W PB W Pad W-15 W-15 V1 PB W Pad W-15 W-15A V10 PB W Pad W-15 W-15P61 V6 PB W Pad W-15 W-15P62 V1 PB W Pad W-16 W-16 V3 PB W Pad W-16 W-16A V3 PB W Pad W-16 W-16AP61 V1 PB W Pad W-16 W-16L1 V3 PB W Pad W-17 W-17 V4 PB W Pad W-18 W-18 V1 PB W Pad W-19 W-19 V2 PB W Pad W-19 W-19A V1 PB W Pad W-19 W-19AL1 V3 PB W Pad W-19 W-19AL1PB1 V1 PB W Pad W-19 W-19AL1P62 V1 PB W Pad W-200P61 W-200PB1 V7 PB W Pad W-200 W-200 V6 PB W Pad W-201 W-201 V4 PB W Pad W-207 W-207 V10 PB W Pad W-207 W-207P61 V2 PB W Pad W-20 W-20 V1 PB W Pad W-211 W-211 V9 PB W Pad W-212 W-212 V12 PB W Pad W-215 W-215 V7 PB W Pad W-215 W-215PB1 V2 PB W Pad W-21 W-21 V3 PB W Pad W-21 W-21A V12 PB W Pad W-22 W-22 V1 PB W Pad W-23 W-23 V3 PB W Pad W-23 W-23A V5 PB W Pad W-24 W-24 V1 PB W Pad W-26A W-26A V6 PB W Pad W-26 W-26 V1 PB W Pad W-27 W-27 V3 PB W Pad W-27 W-27A V3 PB W Pad W-29 W-29 V1 PB W Pad W-30 W-30 V1 PB W Pad W-31 W-31 V1 PB W Pad W-32 W-32 V6 Reference Offset Ctr-Ctr No-Go Allowable MD MD Distanc e Area` Deviation;. Warning ft fY ft ft ft 5300.00 5900.00 2493.44 170.77 2322.67 Pass: Major Risk 5351.67 5300.00 763.51 168.72 594.79 Pass: Major Risk 7022.21 7400.00 751.93 158.75 593.18 Pass: Major Risk 7022.21 7400.00 751.93 158.75 593.18 Pass: Major Risk 7022.21 7400.00 751.93 158.75 593.18 Pass: Major Risk 7022.21 7400.00 751.93 158.75 593.18 Pass: Major Risk 8454.01 9000.00 769.45 159.01 610.44 Pass: Major Risk 8454.01 9000.00 769.45 158.90 610.55 Pass: Major Risk 8454.01 9000.00 769.45 158.90 610.55 Pass: Major Risk 8454.01 9000.00 769.45 159.01 610.44 Pass: Major Risk 14299.67 5300.00 0.00 157.60 -157.60 FAIL: Major Risk- 8100.00 8300.00 2198.52 107.51 2091.01 Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range 5359.99 5800.00 2046.37 117.81 1928.56 Pass: Major Risk 5333.18 5600.00 2222.69 112.60 2110.09 Pass: Major Risk Out of range 8230.09 8400.00 1327.38 117.39 1209.98 Pass: Major Risk 5341.81 5700.00 1762.23 201.62 1560.61 Pass: Major Risk 5359.03 5400.00 223.24 148.47 74.77 Pass: Major Risk 5300.00 5400.00 2168.40 95.10 2073.30 Pass: Major Risk Out of range 6299.16 6400.00 2387.70 98.92 2288.79 Pass: Major Risk 12288.62 14892.00 785.87 242.87 543.00 Pass: Major Risk 7669.48 7800.00 2494.83 100.43 2394.40 Pass: Major Risk Out of range Out of range 6242.68 6300.00 2800.15 82.09 2718.06 Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Schlumber er g Anticollision Report Company: BP AmoCO Date: 7/19/2005 Time: 0$:44:41 Page: 2 ;Field: Prudhoe Bay Reference. Site: PB W Pad Co-ordinate(NE) Reference: WeIC W-17, True North Reference Well: - W-17 - Vertical (TVD) Reference: W-17A Plan 81.'.3 Reference WellpatlP.lanV1/-17A Db:'OraCle Summary <----------- --------- Offset Wellpath =---------- ----------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpatb MD MD Distance Area- Deviation `Warning ft ft fti ft ft - PB W Pad W-32 W-32A V3 Out of range PB W Pad W-32 W-32AP61 V12 Out of range ~OST THIS NOTICE IN THE DOGHOUSE W-17A Rig site Summary of Drilling Hazards / Standard Operating Procedures for H2S precautions should be followed at all times. The highest concentration currently on record is 25 ppm, measured in 2005. / NORM test all retrieved well head and completion equipment. / The closest neighboring wells, at surface, are W-16 and W-18. Well W-18 is approximately 35' to the North. Well W-16 is approximately 35' to the South. No shut-in should be required, but care should be taken during rig MIRU and RDMO. Use spotters as necessary. / The de-completion of the 3'/2", 9.2#, L-80 tubing may be difficult due the fact that the tubing may be corroded from 2,250' to 2,700'. / It will be necessary to mill a section, rather than exit via whip stock. Care should be taken to thoroughly clean the well bore of cuttings. Follow the Section Milling `RP'. / There are two planned fault crossings in drilling the intermediate interval, at approximately 6,560'md, and 8,425'md. The first fault should be within the upper Colville. The second fault is crossed in the Miluveach. Each is deemed a low to moderate risk for lost circulation. Adequate planning and preparation will be prudent. / Differential sticking may be encountered. Overbalance is approximately 500 psi. Always follow established drilling and connection practices for stuck pipe prevention. / Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. CONSULT THE W-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. W-17A W-17 Pie Rig ~ • 13 3/8", 72.0#, 2,854 L-80, ID = 12.347" Pre rig tubing - chemical cut 7,800 Pre rig cement P&A 11,000 ~ TOP OF 7" LNR 11,160 ID = 2.992" 11,195 9 5/8", 47.0#, 11,417 L-80, ID = 8.681 " PBTD 11,932 7°, 26.0#, L-8o, 11,973 U4S liner s o`. .• .: • ,,, • ~~~ • ~ .®~ .; ~~ ~ .~ a :, SAFETY NOTES: TBG HOLES @ 2250', 2274' & 2672' MD. 2,096 3 1/2" OTIS SSSV Landing nipple, ID = 2.75" Minimum ID = 2.750" @ 2096' 3-1 /2" OTIS SSSV NIPPLE TREE = 3" MCEV OY WELLHEAD= MCEVOY ACTUATOR= OTIS KB. ELEV = 81.62' BF. ELEV = 53.71' KOP = 1484' Max Angle = 52 @ 11848' Datum MD = 11492' Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3271 2920 40 OTIS RA 5 7034 5638 47 OTIS RA 4 8772 6922 40 OTIS RA 3 9782 7673 45 OTIS RA 2 10476 8141 48 OTIS RA 1 11076 8533 51 OTIS RA 11,107 3 1/2" PARKER SWS NIP, ID = 2.750" 11,116 9 5/8" X 3 1 /2" OTIS PKR, ID = 2.750" 11,162 3 1/2" PARKER SWS NIP, ID = 2.750". Tubing Tail F1ug set 09123,%02 11,183 3 1/2" PARKER SWS NIP, ID = 2.750" 11,195 3 1/2" WLEG 11,162 R;I1 tubing tail plug from laming nipple. PERFORATION SUMMARY REF LOG: BHC - GR ON 07/05/88 ANGLE AT TOP PERF: 50 @ 11627' Note : Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 6 11627-11653 O 02/08/94 2-1/8" 4 11653 - 11673 O 05/07/89 2-1/8" 4 11684 - 11709 O 05/07/89 2-1/8" 4 11709 - 11720 O 09/08/90 DATE REV BY COMMENTS DATE REV BY COMMENTS 9/88 ORIGINAL COMPLETION 10/20/02 PP/KAK CORRECTIONS 10/16/90 JO ORIGINAL COMPLETION 05/31/05 dew Proposed pre rig work 02/09/01 SIS-QAA CONVERTEDTOCANVAS 03/05/01 SIS-LG FINAL 09/05/01 RN/TP CORRECTIONS PRUDHOE BAY UNff WELL: W-17 PERMff No: 1880950 API No: 50-029-21856-00 SEC 21, T11 N, R12E, 766' FNL ~ 1183' FEL BP F~caloration (Alaska) W-17A Propped CompletioR~ 13 3/8", 72.0#, 2,854 L-80, ID = 12.347" 2,200 4 1/2"'X' landing nipple 9 5/8" X 7" Baker FlexLock 5,000 liner hanger, ZXP liner top packer w /TBS 5,250 Window in 9 5/8" casing TREE= 41/16" WELLHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV = 81.62' BF. ELEV = 53.71' KOP = 1484' Max Angle = 52 @ 11848' Datum MD = 11492' Datum TV D = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VALVE LATCH 3 TBD TBD 4 1/2" X 1" KBG-2 DCK BK 2 TBD TBD 4 1/2" X 1" KBG-2 DMY BK 1 TBD TBD 4 1/2" X 1" KBG-2 DMY BK 10,150 -{ 4 1/2"'X' landing nipple 10,170 7" X 4 1/2" 'Baker S-3 Pkr 10,190 4 1/2"'X' landing nipple 10,210 4 1/2" 'XN' landing nipple 7" X 5" Baker HMC liner 10,225 hanger, ZXP liner top Pre rig cement P&A 11,000 ~`"' ~ ~` acker w /TBS P ',~; \ 10,377 7", 26.0#, L-80 BTGM casing TOP OF 7" LNR 11,160 3 1/2", 9.2#, L-80, 11,195 ID = 2.992" 9 5/8", a7.o#, 11,417 L-80, ID = 8.681" 4 1/2", 12.6#, L-80, TGII tubing 10,222 12,324 4 1/2", 12.6#, L-80, IBT-M liner PBTD 11,932 7", 2s.o#, L-8o, 11,973 U4S liner DATE REV BY COMMENTS DATE REV BY COMMENTS 9/88 ORIGINAL COMPLETION 10/20/02 PP/KAK CORRECTIONS 10/16/90 JO ORIGINAL COMPLETION 08/01/05 dew Proposed completion Wp04 02/09/01 SIS-QAA CONVERTED TO CANVAS 03/05/01 SIS-LG FINAL 09/05/01 RN/TP CORRECTIONS PRUDHOE BAY UNff WELL: W-17A PERMfT No: API No: 50-029-21856-01 SEC 21, T11 N, R12E, 766' FNL & 1183' FEL BP Exploration (Alaska) • • Subject: W-17A quarter mile radius wells From: "Wesley, Dave E" <WesleyDE a BP.com> Date: Fri, 05 Aug 2005 10:57:20 -0800 To: Winton aubert(~?admin.state.ak.us Winton, There are three wells which lie within a quarter mile of the planned W-17A. ~ ~ j W-15A is -874' at 11,610' and in the drilling well W-17A. ?~LISI (tRoos~) Iqo osb W_16 is _1,191' at 10,560' and in the drilling well. W-16 is plugged below 10,880', as this is the window depth for W-16A. W-16A moves away from W-17A. W,i7 ~$$dq~~ W-21A is -789' at 12,227 and in the drilling well W-17A. 201 ! ~~ (I ~k o 3 t~ i ~ 22 • 1(-I Z t~G o09 ~ Anywurther questions, please call. Regards, Dave Wesley, Jr. GPB Drilling Engineer 564-5153 office 440-8631 cell BP EXp ~ HUBg~E AI~CHORq ~ 6Q2 MB AK -NC E qK 5 M 9951 g-66.12 astercarq Check s9-sn252 2 ~ 5 PAY TO THE ORDER OF RATE First;National Anchorage, k Alaska ~ $ ~~ Qv AK 9950'1. MEMO:.. ~ DpLLgRs . i 25 2poO6o,.9 ~, 9it,..,62~?~n3556~~~ `~ 0 ,~ .\ • • 2 ~ • TRAANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~BGe Ltl - /7~I Development Exploration Service Stratigraphic CHECK Wl3AT ADD-ONS "CLUE" APPLIES (OPTJONS MiJLTI The permit is for a new wellbore segment of LATERAL existing well ~ . Permit No, •~ API No. (lf API number Production. should continue to be reported as last two. (2) digits a function•of the original API number. stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all CPS records, data and logs acquired, for the pilot . bole must be clearly differentiated •in both • name (name on permit plus PIi~ and API number (50 - 70/80) from records, dais and logs acquired • for well (name on permit). SPACDVG The permit is approved subject •to full EXCEPTION compliance with 20 AAC 25.OSS. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing ~ e=ception. (Company Namel assumes ibe liability of any protest to the spacing .exception that may occur. . DRY DJTCN ~ All dry ditch sample sets submiried to ibe SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and . ] 0' sample intervals through target zones. WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOEOlL-640150 Well Name: PRUDHOE BAY UNIT W-17A Program SER Well bore seg ^ PTD#:2051220 Company BP EXPLORATION (ALASKA} INC Initial Classfrype SER / PEND GeoArea 890 Unit 11650 OnlOff Shore On Annular Disposal ^ Administration 1 Permit-fee attached--__--__ - - - Yes- -------------------------_-_--_ - 2 Lease number appropriate_ - - - _ _ - _ Yes - _ - Addition made to 10-401-: -Su_rface_and top_prod, int. in ADL 028263;_TD in ADL 047451.- _ _ _ _ _ _ _ _ _ _ - - - - 3 Unique well-name andnumber___~ __ ~_ ~__. __ ~____~ _ _ _ __ YeS- ---- _ _~_ __~__ ~_ 4 Well located in a_definedpo4l__-__----__.___ ----_______ _________Yes_ -,__PRUDHOEBAY,PRUDHOE OIL,640150, governed by CO341_D,_____-_--_-___-__--.-_-- 5 Well located proper distance_from drilling unit boundary- _ Yes - . - - CO 341 D has no testridions to well spacing except-500' from boundary of affected area.- - - - - - - - - 6 Well located properdistance_fromotherwells__--__---____--_-- -__--____Yes_ -_------------------------------------- - - 7 Sufficient acreage,~ayailable in-d_ril_ling unit - - -- Yes - - - - - -- - - - - 8 If deviated, is-wellboreplat_included-_--__-_____--__ ---____ __---- -_Yes_ _____________________________________----_-__- 9 Operator gnly affected party- - - - - - Yes - - - - - - -------------------------------- 10 Operato[has_appropriate_bondinfQrce_______________________ _________Yes_ _--.-_CQrre~tbondngmberis#5194193,---_..-_--.--__-----._-_-----. ----------------- 11 Permit can be issued without conservation order Yes - -- ------------ Appr Date 12 Permit can be issued without administrative_app[ova_I---------------- ---------Yes_ _-__--.__---_-_. ------------ SFD 81412005 X 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by_InjQetion Order # (put1O# in_comments)-(For_ Yes - Area Injection Order No._ 3. 15 All wells-within 114-mile area of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ - - _ _ Kuparuk 22-11-12, PBU W-15, W-15A, W-1ti, W-17, W-21A. _ - _ ... _ _ . _ - _ _ - _ _ _ - , _ _ _ _ _ _ _ _ - _ _ -- 16 Pre-produced inject9r_ duration of pre p[oductign Less than 3 months (For service well_ only} - . No_ - - _ - - - - _ - - - 17 ACMP-Finding of Consistency_has been issued_for-this pro)ect_ _ _ _ - - _ NA_ _ . ---------------------------------------------------- Engineering 18 Conducto[string_provided_-___._____-____-___-_-__.-__ -_-____- NA-- --------- ----- ----------------------------------------------------------- 19 Surface casing_protectsall-known U$DWs - - - NA- - 20 _C_MT.vol_adequate-tocirculate_oncond_uctor&su_rf_csg____--___--__- _-___-__NA__ ________________________---__-__--__-----_---__--__---_----_-__ -__ 21 CMT_v_ol-adegu_ate_t9 tie-in long string tosurf csg- - Nq - - - . - - - 22 CMTwillcoverallknown_pro_ductiyehorizons_____________________ ___ _____Yes_ _-____Adequateexcess,_______-_------__--__ --- 23 CasingdesynsadequafeforC,T,B&_permafr_ost--______________ ____- __,Yes_ _-___--________-__---__--___--__--_-.__--_____-__---- --__- ------------ 24 Adequate iankage_orre_servepit________________________-_ _-.___--_Yes_ _--_Nabors_lES,-___-___- 25 If_a_re-drill, has-a-10.403 for abandonment been approved - - Yes - - 7!28!2005._ - _ - - 26 Adequatewellboreseparation_proposed-___________________-_ __--___--Yes- .___-,-_ ------------------------------------------------------------------ 27 Ifdiverterrequired,doesitmeetregulations___-__-------------- --------- NA-- ______Sidet[ack..___-_-__--__-- - - - - Appr Date 28 Drillingfluid-programsehematic&equiplistadequate______________- ----__-__Yes_ __-___IvlaxfulW_10,9_ppg.-__-___-_-_____-,____--__-----.-_--__-_--__--_-- WGA 8!1012005 29 BOPEs,dotheymeet_regulation_____-_-____ --------------- Yes_ -- _--_-.__------------------------------------------------------- 30 BOPE_press rating appropriate; test to (put prig in comments)_ _ _ _ - Yes _ - _ - Test to 4000-psi. _MSP 2520 psi._ - - - - 31 Choke_manifoldcomplieswlAPl_RP-53 (May84)______ ____________ _________Yes_ __________-_-__-_- ----_----__--__. 32 Work will occur without operation shutdown_______--__-____- --_--_._Yes- _________________________---_--___--__ - - 33 Ispresence_ofH2$gas_probable____________________________ _________ No-- -___NotanH2Spad.--__-- 34 Mechanical.condition of wells within AOR verified [For_service well only) - - _ - - Yes Records indicate mechanical integrity of all_AOR wells._ - - - _ _ _ - - - Geology ' 35 Permit_can be issued w/o hydrogen_sulfidemeosures - _ - - - . - - No- Nearby well W-15A measured 25 ppm H2S. - _ --------------------------- 36 Data_presented on-potential overpressure zones- - _ - Yes _ - _ Reservoir pressu[e_expected io be_7.4 ppg EMW;_will be_drilled.with 9,0--10.9.ppg mud to topSag, then 8.5 r Appr Date 37 Sefsmicanalysis-of shall4wgas-zones- - - _ _ _ - - - _ _ - - NA- _ - _ _ _ _ - _ 8.6 ppg mud-through_rQServofr._ _ _ - _ - - - - SFD 81412005 38 Seabed conditionsurvey_(ifoff-shore}_____________ __ __--__-- NA__ __-___-_-. 39 _Conta_cknamelphone forweekly progress_reports [exploratory only]- NA_ - Geologic Engineering Public Commissioner: Date: Commissioner: Date Com er Date •
