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209-102
7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name: Authorized Title: Authorized Signature: Date: Contact Name: Contact Email: Contact Phone: COMMISSION USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE COMMISSIONCOMMISSIONER PBU W-25A Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-102 50-029-21874-01-00 341H ADL 0028262, 0028263 11240 Conductor Surface Intermediate Liner Liner 9013 80 2636 10047 287 1596 11187 20" 13-3/8" 9-5/8" 7" 2-3/8" 8986 41 - 121 40 - 2676 39 - 10085 9813 - 10100 9624 - 11220 2670 41 - 121 40 - 2676 39 - 8744 8524 - 8756 8372 - 9003 None 2260 4760 5410 11780 None 5020 6870 7240 11200 10325 - 11175 3-1/2" 9.3#L-80 37 - 98698880 - 8981 Structural 3-1/2" TIW Packer No SSSV Installed 9742, 8467 No SSSV Installed Date: Stan Golis Sr. Area Operations Manager Torin Roschinger Torin.Roschinger@hilcorp.com PRUDHOE BAY, PRUDHOE OIL 9/2/2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 10:49 am, Aug 20, 2021 321-410 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.08.20 09:24:07 -08'00' Stan Golis (880) X 10-404 DSR-8/20/21MGR21AUG21DLB 08/30/2021 dts 8/31/2021 JLC 8/31/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.01 10:17:06 -08'00' RBDMS HEW 9/2/2021 Add/Re-Perfs to Increase Gross Fluid Rate W-25A PTD: 209-102 Well Name:W-25A API Number:50-029-21874-01 Current Status:SI Producer Rig:Coil Estimated Start Date:September 2021 Estimated Duration:3days Regulatory Contact:Abbie Barker Permit to Drill Number:209-102 First Call Engineer:Brian Glasheen (907) 545-1144 (c) Second Call Engineer:Torin Roschinger (406) 570-9630 (c) AFE Number:212-00884 Current Bottom Hole Pressure:3543 psi @ 8,800’ TVD 7.8 PPGE Maximum Expected BHP:3550 psi @ 8,800’ TVD 7.8 PPGE Max. Anticipated Surface Pressure:2670psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:350 psi on 4/13/2021 Min ID:1.82” at 3-1/2” LT Staddle Packer @ 9,592’ MD Max Angle:88 Deg @ 10,431’ Tie-In Log: W-25A SLB Memory GR/CCL 8-Dec-2009 Brief Well Summary: W-25A is a horizontal Ivishak producer completed in 2010. The nearby parent bore cum’d 1.6 mmbo before developing a packer leak resulting in Zone 3 water production resulting in the water cut jumping from ~ 65% to > 90%. Subsequent squeeze efforts had little effect and the decision was made drill a coil sidetrack to regain offtake in the area. The current bore has produced 0.2 mmbo and was last tested in 2018 at 173 bfpd, 53 bopd (69% WC, 2354 scf/stb GOR). The current bore was not SIT’d in time post drilling and has have always struggled with low PI, plateauing around 500 bfpd, with spikes surrounding acidizing and addperf jobs. The low liquid rates result in hydrating issues; the well has been SI since 2018 due to low fluid rate and a hydrate. The well is still competitive from a TGOR and WC perspective. Ultimately the goal for W-25A is to increase PI and get the well back online. The last acid job (2017) increased the fluid rate by 100 – 300 bfpd (depending on flush production). Going forward, the team discussed re- perfing, acidizing, or frac’ing the well to stimulate. Frac’ing the heel was ruled out due to proximity to the parent bore and risk to water production. Acidizing and reperfing are both viable options at this point as long as they’re followed by an SIT. Objective: The objective of this program is to increase gross fluid rate by shooting 675’ of extended add/re-perfs. In addition, an SIT will be pumped to reduce scaling in the near wellbore area. Sundry Procedure (Approval Required to Proceed): Note: The well will be killed and monitored before making up the initial perfs guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. Coil Tubing 1. Prior to CT RU, verify that SIT chemicals are in stock and the SIT can be performed by Fullbore immediately after perf guns are shot. * -00 DLB Add/Re-Perfs to Increase Gross Fluid Rate W-25A PTD: 209-102 2. Bullhead 110 bbls of KWF, 8.4 ppg brine down the tubing to the formation. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSL.) a. Wellbore volume to bottom perf = 89 bbls b. 3-1/2” Tubing – 9,592’ X .0087bpf = 83 bbls c. 2-3/8” Liner – 1,583’ X .0039bpf = 6 bbls (to bottom perf) 3. MU 1.75” JSN with logging tools and & RIH. Tag PBTD. PUH and flag pipe for subsequent perf gun runs. POOH and confirm good data. 4. At surface, prepare for deployment of TCP guns. 5. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg brine as needed. Maintain continuous hole fill taking returns to tank until lubricator connection is re-established. 6.Pickup safety joint and TIW valve and space out before MU guns.Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 7. Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. W-25A Perf Schedule *1.56” perf guns were used to calculate gun weights. Perf Interval Perf Length Gun Length Weight of Gun (lbs) 10327-10377’ 10382-10407’75 80 ~300lbs (3.62ppf) 10539-10629’ 10639-10969’420 430 ~1560lbs (3.62ppf) 10989-11106’ 11116-11176’180 190 ~700lbs (3.62ppf) 8. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. POOH. a. Note any tubing pressure change in WSR. 9. POOH. Stop at surface to reconfirm well dead and hole full. 10. Review well control steps with crew prior tobreaking lubricator connection and commencing breakdown of TCP gun string. 11. Repeat steps 4-10 for subsequent guns. 12. FP well and notify the operator not to POP well until SIT is pumped. 13. RDMO CTU. End of Sundry Request (10-404 to be submitted after this step is complete) Fullbore 1. Perform SIT per the following: a. Scale inhibition notes: i. This bullhead treatment should be performed as soon as possible to prevent scale deposition. MU PCE. * See note above regarding kill methods if pressure observed at surface after perforating. Standing orders flow chart included with this sundry request. Add/Re-Perfs to Increase Gross Fluid Rate W-25A PTD: 209-102 ii. Contact C-pad chemicals (659-8725) for the Scaletrol 720 and Techniwet 4353. It is supplied in totes. Have the truck transporting the chemical pill load the inhibitor, then load the remaining 120-160 F water from the hot water plant (water temperature is not critical, warm water is just to minimize freezing problems). No further mixing is required beyond the drive to the wellsite. iii.NO METHANOL can contact the scale inhibitor; it will cause precipitation.Diesel should be used for pressure testing lines and any pumping that needs to be done before the scale inhibitor slug is pumped. iv. Design basis for wax bead diversion is approximately 1 lb beads per foot of perforations (675# total). v. Ensure that pump is clean and all fluids should be filtered to 3 microns at place of origination prior to pumping downhole. 2. Confirm the lift gas is turned off. 3. Load IA with dead crude or diesel in preparation for pumping down tubing. Well has liner top straddle packer with a differential rating of 2500 psi. With fluid gradient and applied surface pressure this rating would be exceeded if IA is not loaded.Max pumping pressure at surface for entirety of the job will be 1400psi in order to maintain differential below 2500psi.Screened Orifice is at 9386’ MD so expected volume of crude is 575 bbls. Pump at 5bpm until back-pressure is obtained indicating fluid is at the live GLVs and slow pump rate to 1-2bpm. 4. Pump the following SIT fluid schedule at 3-5 bpm if possible while loading tubing and displacing gas from wellbore. After tubing is displaced with treating fluids, reduce rate to a maximum surface treating pressure of 1400 psi. Record pump rates, tubing, IA and OA pressures throughout the job. Do not exceed 1400psi wellhead pressure at any point within the job- even when wax beads hit the perfs. If wax bead diversion works excessively well, it may be necessary to shut down the pumps and allow the wax beads to warm and melt some in order to finish the job. SIT Pumping Schedule Stage Volume (bbls) Fluid Preflush 55 1% Techni-Wet 4353 in seawater or 1% KCl SCALE INHIBITOR SLUG 80 10% Scaletrol 720 w/ 0.25% Techni-Wet 4353 in seawater or 1% KCl OVERFLUSH 160 1% Techni-Wet 4353 in seawater or 1% KCl WAX BEAD DIVERSION 11 675# wax beads mixed at 1.25 ppg in 2% SWS Oilseeker (J570) mixed in 3% KCL Preflush 55 1% Techni-Wet 4353 in seawater or 1% KCl SCALE INHIBITOR SLUG 80 10% Scaletrol 720 w/ 0.25% Techni-Wet 4353 in seawater or 1% KCl OVERFLUSH 160 1% Techni-Wet 4353 in seawater or 1% KCl TUBING DISPLACEMENT 61 1% KCl or seawater FREEZE PROTECTION 22 Dead crude or diesel 5. Shut down pumping and RD. Ensure that the well remains shut-in and gas lift turned off for 12 hours. Add/Re-Perfs to Increase Gross Fluid Rate W-25A PTD: 209-102 6. Contact the GPB Lab supervisor at 659-5654 to notify them of the job and estimated POP time. They will coordinate post job sampling. 7. POP well after 12 hours. 8. Obtain produced fluid samples once per day for 1 week after the treatment. Obtain produced fluid samples once per month for ~2 years post treatment or until scale inhibitor returns diminish to the point the well needs to be inhibited again. These samples should be analyzed for Ba, B, Ca, Fe, Sr, P, and Sulfate. Add well to GPB lab sampling request list and scale inhibition tracking spreadsheet. 9. Obtain a well test after well production stabilizes. Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Equipment Layout Diagram 5. Standing Orders for Open Hole Well Control during Perf Gun Deployment 6. Mini Log 7. Tie In Log Add/Re-Perfs to Increase Gross Fluid Rate W-25A PTD: 209-102 Current Wellbore Schematic Add/Re-Perfs to Increase Gross Fluid Rate W-25A PTD: 209-102 Proposed Schematic Add/Re-Perfs to Increase Gross Fluid Rate W-25A PTD: 209-102 Coiled Tubing BOPs Add/Re-Perfs to Increase Gross Fluid Rate W-25A PTD: 209-102 Equipment Layout Diagram Add/Re-Perfs to Increase Gross Fluid Rate W-25A PTD: 209-102 Standing Orders for Open Hole Well Control during Perf Gun Deployment Add/Re-Perfs to Increase Gross Fluid Rate W-25A PTD: 209-102 Mini Log Add/Re-Perfs to Increase Gross Fluid Rate W-25A PTD: 209-102 Tie-In Log Add/Re-Perfs to Increase Gross Fluid Rate W-25A PTD: 209-102 Add/Re-Perfs to Increase Gross Fluid Rate W-25A PTD: 209-102 Add/Re-Perfs to Increase Gross Fluid Rate W-25A PTD: 209-102 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: August 19, 2021Subject: Changes to Approved Sundry Procedure for Well W-25ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM 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 0 Other Stimulate ® Alter Casing 0 Change Approved Programf ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other. Yli//C� Q C7 C 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 209-102 3. Address: P.O.Box 196612 Anchorage, Development I1 Exploratory 0 AK 99519-6612 Stratigraphic 0 $ecce 0 6. API Number 50-029-21874-01-00 7. Property Designation(Lease Number): ADL 0028263 8. Well Name and Number. PBU W-25A 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: RECEIVED Total Depth: measured 11240 feet Plugs measured feet ft true vertical 9013 feet Junk measured feet AUG 15 2017 Effective Depth: measured 11187 feet Packer measured 9743 feet true vertical 8986 feet Packer true vertical 8468.48 feet GCv Casing: Length: Size: MD: TVD: Burst Collapse: Structural Conductor 80 20"Conductor 41-121 41-121 Surface 2634 13-3/8"68#L-80 40-2674 40-2674 5020 2260 Intermediate 10046 9-5/8"47#L-80 39-10084 39-8743 6870 4760 Production Liner 288 7"26#L-80 9812-10100 8524-8756 7240 5410 Perforation Depth: Measured depth: 10325-10370 feet 10390-10400 feet 10540-10625 feet 10645-10905 feet 10930-10970 feet 10990-11070 feet 11095-11105 feet 11125-11145 feet 11160-11175 feet True vertical depth: 8880-8888 feet feet 8890-8890 feet 8899-8906 feet 8909-8933 feet 8935-8939 feet 8941-8950 feet 8955-8957 feet 8963-8969 feet 8975-8981 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.3#L-80 37-9870 37-8570 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 0 10325'-11175' / f,�(�gp Treatment descriptions including volumes used and final pressure:"'N�� '4v yQ�� 330 Bbls 3%NH4CL w/F103,80 Bbls 9:1 HF Acid,84 Bbls 12%HCL Acid,24 Bbls Slick 1%KCL w/Safelube,92 Bbls Diesel,1568 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 141 331 180 1335 227 Subsequent to operation: 149 98 328 1221 330 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development O Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Peru,Cale Contact Name: Peru,Cale Authorized Title: Petroleumjeer Contact Email: Cale.Peru©bp.com Authorized Signature: Date: 907/7 Contact Phone: +1 9075644522 Form 10-404 Revised 04/2017 r 14 7 j�` *" l RBDMS 0 v AUG ` 3 201 Submit Original Only • • RECEIVED AUG 152017 AOGCC 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 August 14, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Acid Stimulation of Well PBU W-25A, PTD # 209-102. 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 • • Packers and SSV's Attachment PBU W-25A SW Name Type MD TVD Depscription W-25A PACKER 9592.13 8346.54 3-1/2" Baker KB Top Packer W-25A TBG PACKER 9743.26 8468.48 3-1/2"TIW Packer • • ± ns � E a 5 'F,> > > ao o a) ) a v z > 3 m > 3 u) - x - = = = ° c o ° � cr• ate) > a`o N .0 O o Oc 'Sm ca T- °off C)iU 0_ a) . a) N-c c ,- c ,c c 3 3 c ti c _ CO U) - � c v a � Q ar 'o a '• sa c cw cU z = °'m = � N = o Up Cl) L !n ` 3 u Y E J N C a) L O N O • a) o a) a) 0 N m m v m O m 0: N ., -0 m c O m U _ N U • N C O n. a) U O 0 0 O U ado � 0 c c,!) co U � -o Eo a- iC O L V Y O -in co -) � N • C 0_Ce M O r OO O a O O1- - O O C C >- c D L c -4-4 ,� m U 3 ?� U o 0 ( < Q 3 O 3 m Q c0 3 0 3 o ) .. v ° o c U L ~ Q x O. _, C> 0)j, 0)j 0)— *K +O 0_ m 0)= N 0) * a) = U = ? V _ - Ccs = � .- oo •rz ;41 m 12 o m ov) o '~ o o Q r-- -5 (DEE o ° ° o uu'i _ = 1:1 00 M QM M M +O , 0 • M L a) M Q O a-T C • m J U• J J M J r- (/) Cl_ 70 a) o O J — C J — .- O U N c a o o � on 04 = 0 oa � 0 - - E 0 O - oQ 0 ;C tri cri • co- • uSom -• -02 `- m `no I- 0 `ro "Lv = l ,,,c- CL d >N> N> N I's Nc ,. 3 � •• M >N> � a) Jl0 N � �: 0 O c Q- > � 9NM u) QO O2 a) O N > (o1- O � � (n O2 mu- •- A JNJN JN- JZ O o O 61- en0 J2Q UD J � U N :° O — ` — p — p SCO coio_ c4- • EU u N _ � « c°i O rn � _ .. o c� � coc * � w � vii o o F- � m � ° • oQ VI - C p C C C "- ,o * = u) E4- __. N C "- U — 3 N o * 0 fr > > > v * U >, , o u) D -c o O 0 - _ g c � a) �. �. .. in a) H a) * o -“ a) .-. a) U 1 a. _ a) b c o m aiCn� moaNi ° ) c00_ v� 2aiou) u) a- rn 1. iii 1- 1- w 1- 4-- 1- ;_, - N - Y O L c0i aNi c N O = N c ,-? (A p Q - O - N N O F- 0) . 0 c U a) 0- 1- O 'N 0_ u_ F- O - N - > m O D )) a) a) O 3 C -0 C 4) < (A a) "0 U > a ° 0o0 Low a) O Cl) ° •- U Uo �Q L E a) >' .E >' .5N- � D0- * O Qv -c 'a -a a w0 *k 0- 4i ca--a m .t (n c (n cpmDm con E v -0 � m > 0JJ2 m > = _c, E a -° (4. � _1r- _1COmCU mF-0 < 0 -• :� _10U0M 0 -) 0O . -I (/) (i � u) . w I- 0 N - N- N- N- N- N- N- r- N- r` 0 0 0 0 0 0 0 0 0 NC-) > N Cr) \) co (0 (0 CLCD N- N- �, N- N- N- N- N- N- N- N- 1 r-- 0 `0 Q • • • a a) a c - :_. T; T; a� c N 0) U) 0 a) (1) Cl) U > > > 05 Co oO N a) a) a) 3 c c c Cl) - _ a) - PT ti a) as Cl) vi 5 = O = - L a) ct a) w) a) �/� a) M L• w L L L O co co 03 03 a — C ._ c _ C — N O N O 4) o N a) cc c U) 0 - o of O O C ooo � U a) O a 0 a U a 0 a -9 E L < 0 < 0 < 0 Q o7 Q 0) -- as -... as -... as --. 0 Cl) >^ O. ' -a ' l- 0O Qc0 = 0 = 0 = : 72 O QU M O O Q NZ M Q U M 4.8 43 O 0 5 M Q 8O O �OaO ? O "' CO. cci o ori o o m e > vi I > ccI) cCL cnn � " a) >, J J J J 1 = L •CU E E E r ) a) Q O •+.. O o ... N- O N co 4L- � ` Cl)_ O C C C C � aa) - aa) - aa) O 3o_J C �U- a fN cFa)i— '42 C U _cJ Q • U U > U > a) > v Q J U cn > cn > co > co E a) Z 2 N W C/) Cl) (n W o L • o 0 0 `— c °� J (n J cn J (n J .- U (n d Lo co ei � 0 I's O O co O) O `— m ,— N O M 00p 0�0css N- ° TREES 3 1/8"MCEVOY 5000# • i NOTES: WELL ANGLE>70°@ 10310' "`2-3/8" ELL FEA = MCLOTI W-2 5A PRESS RATING,IS 2500 STRADDLE SID CONTAACT WIE PKR DIFFERENTIAL OR TO ACTUATOR= OTIS i KB BEV= 90.74'I ; MIT-IA PER TTW(01121/10) 18F. ELEV ' _. —54.54' KOP= 2800' 2066' I—OTIS SSSV LANDIdG M3,10=2.750' I Max Angie= 88°@ 10431' Datum MD= 10418'1 GAS LIFT MANDRELS Datum ND= 8800'SS� ji 0 1 STI M) ND'DEV! TYPE VLV LATCH PORT DATE 1 i 13-3/8"CSG,68#,NT-80 BTI2S,D H WD = 12.415" 2676' 5 2985 2985 4 A 0OM_ RM 16 03/29/16' 4 6394 5837 44 MERLA,DOME RM 16 03/29/161 3 18253 7272 37 M3RLA DOW RN 16 03/29/16 2 19386 8180 36 WRLA SO RM 20 03/29/16 1 19604183571 36 I IvE LA I DIM j RM 0 05/06/05 *BEHIND PATCH 9555' ---I3-112"LT STRADDLE R(R,D=1.82'(01/06/10) 1 Minimum ID = 1.82" @ 9555' III 13-1/2" LT STRADDLE PACKER �• • i 9624' I-2.70"BLRDEPLOY SLV,D=2.250" 1 111 44 .44 111 117' H3-1/2"OTIS SLDtIG SLV,D=2.750" 1 # �t 9700' —EST TOP OF CI3AEVT(07/16/06) '1 M1�1 11111 1110.1 11111 I . ? j—TUBING SEAL ASSEMBLY *•1.4 11,1141 ��711 1114 5 9742' (--9-5/8-X3-1/2'TIW PKR,D=4.00' '1'0 1/ i 1 P1'4 1111111 1+4►111 BEI-IIND 1+1I x'11 11t1.1.t 9803' H3-1/2"PARKER X NP.ID=2.75" CT LNR TOP OF 7'LNR — 9813' 0.4 •/ 11,11/. 1111411 114;t I 9835' h3-1/2"PA RKER X NP,D=2.75" 41111 4,0 0u,4 3-1/2"TBG,9.3#,L-80, 0087 f,ID=2.992" —{ 9869' 1�1�/ 1A1149869' I—3-1/2'ThN WLEG,D=2.992" 144.11/ 11l1�I,. F +X11/ 14 414 987T E—ELMD IT LOGGED??/??/?? I�i4.4 1.114 0141 9900, EST BOTTOM OF CEMENT(07/16/06) 9-5/8"CSG,47#,L-80,NSCC,D=8.681" H 10085' I 41 •1111 1#1.1 4111 11/14 ML.OUr W DOW(W-25A) 10100'-10105' 2.74"PILOTI-OLEWIIPSTOCK — 10100' �1�1� �1�14 i 7"LW.,26#,L-80 LJ4S, 0383 bpf,D=6.276" H 10650' AV�`��. *. X111 V. 11 /111.1#1.�R1l. PERFORATION SUMMARY .......l. MW ,1N1111 REF LOG. BHI D GR/MFR ON 12/03/09 1111111 4.. ANGLE AT TOP PERF- 76°@ 10325' 1111111111111.t 41'1/11 ` Note Refer b Ptoduction L76 for historical perf data ♦ .**•411 SIZE ' SPF IYTERVAL Opn/Sqz DATE .4111' 41.111 .1.1.1.1.4.1.1.1 1 56" 6 ( 10325-10370 0 12/08/09 I'1'1'1'1V1'1'1 11111111 1 56" 6 I 10390- 10400 0 12/08/09 4...14.4 1 56" , 6 10540- 10625 0 12/08/09 ................4 1 56' 1 6 10645- 10905 1 0 12/08109 _ au 1 56" ' 6 10930-- 10970 0 12/08/09 PBTD(LOGGED 12/08/09) 11187' sore. 1 56" 6 10990- 11070 0 12/08/09 mss' 1 56" i 6 11095- 11105 0 12/08/09 2-3/8"LNR,4.6#,13CR-80, 0039 bpf,ID=1.995" — 11220' 1 56" ! 6 11125- 11145 0 12/08/09 1 56" 6 11160-11175 0 12/08/09 DATE I REV BY GOMMT3+ITS DATE F4EV BY COM�II2JTS PRLDHOEBAY UNT _11/10/88 ORIGINAL COMPLETION 04/01/16 GTW/JM}GLV GO(03/29/16) WELL. W 25A 12/09/09 NORDIC 2 CTD SIDETRACK(W-25A) PI3:MfT No `1091020 03/21/10 CJMSV GLV 00 AR No. 50-029-21874-01-00 1 06/01/10 RR'JM) DRLG DRAFT CORRECTIONS(12/21/09) SEC 21,T11N,R12E,980'FNL&1446'FEL 02/12/11 SW /AGR GLV GO(02/02/11) r 10/02/15 ti RCT/JM) GLV 00(09/23/15) L BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday,July 21, 2016 7:55 PM To: AK, GWO SUPT Well Integrity;AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead;AK, OPS WELL PAD W; Peru, Cale; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep;AK, GWO SR Fullbore WSL;Wallace, Chris D (DOA); Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington, Aras J;AK, GWO SUPT Well Integrity Subject: OPERABLE: Producer W-25A(PTD#2091020) Sustained IA Pressure Above MOASP All, Producer W-25A(PTD#2091020)tubing hydrates have been thawed,the well was put on production and passed a warm TIFL indicating two competent well barrier envelopes.The well is now reclassified as Operable. Please call with any questions or concerns. Ryan Holt (Au-01,4f GBP Alaska-Well Integrity Global Wells scANNE® NOV I 3 2016 vv Organization Office: 907.659.5102 From: • GWO SUPT Well Integrity Sent: Wedne . July 13, 2016 6:32 AM To: AK, OPS GC2 0 ' , 'K, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, ' GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; AK, OPS WELL PAD W; Peru, Cale; 'Re.. James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov) Cc: AK, GWO DHD Well Integrity; AK, • Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; AK, GWO SUPT Well Integrity; AK, GWO SR Fullbore WSL; 'chris. .. ace@alaska.gov' (chris.wallace@alaska.gov); Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrig- ,itch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: UNDER EVALUATION: Producer W-25A (PTD #21. 020) Sustained IA Pressure Above MOASP All, Producer W-25A(PTD#2091020)was reported to have sustained IA casing pr ure above MOASP on 07/10/16. Pressures were confirmed to be TBG/IA/OA=600/2090/400 psi. Downhole Diagno ics attempted to perform a Tubing Integrity Fluid Level test on 07/12/16, but found a suspected ice plug in the tubing.Thecell is reclassified as Under Evaluation, and is on a 28 day clock to be repaired or secured. \„ Plan Forward: 1. Fullbore Pumping:Thaw ice plug 2. Downhole Diagnostics:Warm TIFL 3. Well Integrity Engineer: Further diagnostics as required 1 ��. • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday,July 13, 2016 6:32 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead;AK, OPS WELL PAD W; Peru, Cale; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep;AK, GWO SUPT Well Integrity;AK, GWO SR Fullbore WSL;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington, Aras J Subject: UNDER EVALUATION: Producer W-25A(PTD#2091020) Sustained IA Pressure Above MOASP All, Producer W-25A(PTD#2091020)was reported to have sustained IA casing pressure above MOASP on 07/10/16. Pressures were confirmed to be TBG/IA/OA=600/2090/400 psi. Downhole Diagnostics attempted to perform a Tubing Integrity Fluid Level test on 07/12/16, but found a suspected ice plug in the tubing.The well is reclassified as Under Evaluation, and is on a 28 day clock to be repaired or secured. Plan Forward: 1. Fullbore Pumping:Thaw ice plug 2. Downhole Diagnostics:Warm TIFL 3. Well Integrity Engineer: Further diagnostics as required Please reply if in conflict with proposed plan. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska 4 2016(Alternate:Jack Lau) %WED DEC 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWellInteeritvCoordinator@BP.com From. , D&C Well Integrity Coordinator Sent: Thurs.. - a 31, 2016 5:42 AM To: AK, OPS GC2 OSM; AK, •' C2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wire - !aerations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES G'. t Wells Opt Engr; AK, OPS PCC Ops Lead; Burton, Kaity; AK, OPS WELL PAD W Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well -, Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; ' - man, Eric; Pettus, Whitney; Munk, Corey; Odom, Kristine Subject: OPERABLE: Producer W-25A (PTD #2091020) MIT-IA Passed post valve c e out 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Monday, February 22, 2016 6:32 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg,James B (DOA) Subject: OPERABLE: Producer W-25A (PTD #2091020) TIFL Passed All, Producer W-25A(PTD#2091020) passed a warm TIFL on February 22, 2016 confirming two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions or concerns. Thank you, Kevin Parks SCANNED MAR J. 5 2016 (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Saturday, February 13, 2016 10:04 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov'; 'Regg, James B (DOA)' Cc: AK, D&C Well Integrity Co61d ator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric Subject: UNDER EVALUATION: Producer W-25A (PTD #2091020) Inner Annulus Pressure Exceeded MOASP All, Producer W-25A(PTD#2091020) inner annulus exceeded MOASP ebruary 12, 2016 with T/1/O: 270/2040/500 psi, thus displaying a potential lack of competent well barriers.The well is cui=Teolly shut in to support wellwork being performed on adjacent well W-26A(PTD# 1990810).At this time the well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Operations: Once wellwork on adjacent well allows, put well online 2. DHD: Perform TIFL to determine barrier status 1 S i Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday, September 26, 2015 5:53 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wal lace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; 'jim.regg@alaska.gov' Subject: OPERABLE: Producer W-25A (PTD #2091020) TIFL Passed All, Producer W-25A(PTD#2091020) passed a TIFL on September 26, 2015 after gas lift valve work was completed. This passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions or concerns. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator Global Wells SCANNED AUG 1 72016 GW Organization Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, September 24, 2015 9:19 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; 'jim.regg@alaska.gov' Subject: UNDER EVALUATION: Producer W-25A (PTD #2091020) Ready to Bring on Production for Diagnostic work All, Producer W-25A(PTD#2091020) is now available to bring on line for diagnostic work after slick line has installed a new gas lift valve design. The has been reclassified as Under Evaluation and placed on a 28 day clock so the diagnostic work can be completed. Plan forward: 1. Operations: POP Well 2. DHD: Perform TIFL 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, March 16, 2015 11:04 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity; AK, OPS WELL PAD W; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Pettus, Whitney; Regg, James B (DOA) Subject: NOT OPERABLE: Producer W-25A (PTD #2091020) TIFL failed Attachments: image001.jpg; image002.jpg; image003.png All, Producer W-25A (PTD#2091020)failed a TIFL on 03/13/2015 indicating a lack of two competent barriers in the wellbore. The well is reclassified as Not Operable and is to be secured with a downhole plug until integrity can be restored. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator SOAK MAR 1 8 2015 GVV �,k�aalbVcii: Organiratwri WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Int ity Coordinator Sent: Thursday, February 26, 15 7:52 PM To: AK, OPS GC2 OSM; AK, OPSG field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline OpeTations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Welk Opt Engr; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov'; 'jim.regg@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projeqs Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Pettu3,Whitney Subject: UNDER EVALUATION: Producer W-25A (PTD #2091020)-I4 exceeded MOASP during TAR All, Producer W-25A (PTD#2091020) is now available for diagnostic work. At this time the we 4 a s been reclassified as Under Evaluation so that the well can be evaluated for the high inner annulus reported last win i Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, February 26, 2015 7:52 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity;AK, OPS WELL PAD W;Wallace, Chris D (DOA); Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep;AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Pettus, Whitney Subject: UNDER EVALUATION: Producer W-25A(PTD#2091020)IA exceeded MOASP during TAR Attachments: image001jpg; image002 jpg;W-25A Wellbore Schematic.pdf All, Producer W-25A(PTD#2091020) is now available for diagnostic work.At this time the well has been reclassified as Under Evaluation so that the well can be evaluated for the high inner annulus reported last winter. Plan forward: 1. Fullbore: Pump Hot Oil Treatment (HOT) 2. Operations: POP Well 3. DHD: Perform TIFL 4. WIE: Additional Diagnostics as needed A copy of the wellbore schematic has been included for reference. Please call with any questions. SCANNED 1VR. 4 Thank you, Laurie Climer (Alternate:kei'in Parks) BP Alaska-WellIntegrity Coordinator GWGIo I W&I organ..on WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com From: AK, D& • • -•ri Coordinator Sent: Tuesday, October 22, 20 -. •M To: 'chris.wallace@alaska.gov'; AK, OPS GC • ' ; OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D& - '•- Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES G•: ells Opt Engr; Burton, Kaity; AK, OPS WELL PAD W; 'jim.regg@alaska.gov' 1 TREE= 3-1/8"MCEVOY 5000# SA NOTES: WELL ANGLE>70°@ 10310' "'2-3/8" WELLHEAD= MCEVOY CHR%....E LNR"* LT STRADDLE PKR DIFFERENTIAL ACTUATOR=' OTIS PRESS RATING IS 2500 PSI. CONTACT WIE PRIOR TO KB.E,LEV= 90.74' MIT-IA PERTTW(01/21/10) BF.ELEV= 54.54' it) f KOP 2800' 2066' —I OTIS SSSV LANDING NIP,ID=2.750" Max Angle= 88°@ 10431' 0 Datum MD= 10418' GAS LIFT MANDRELS Datum TVD= 8800'SS ST MD TV 0 DEV TY PE V LV LA TCH PORT DATE 5 2985 2985 4 MERLA DOME RM 16 03/20/10 13-3/8"CSG,68#,NT-80 BTRS,ID=12.415' —I 2676' 4 6394 5837 44 MERLA DOME RM 16 03/20/10 3 8253 7272 37 MERLA DOME RM 16 03/20/10 2 9386 8180 36 MERLA SO RM 20 02/03/11 1 9604 8357 36 MERLA DM Y` RM 0 05/06/05 'BEHIND PATCH 9555' —13-1/2"LT STRADDLE PKR, ID=1.82"(01/06/10) 1 Minimum ID = 1.82" @ 9555' 3-1/2" LT STRADDLE PACKER �• • 9624' -12.70"BLR DEPLOY SLV,ID=2.250" I 111 1i 111 11 ' 9697' —13-1/2"OTIS SLIDING SLV,ID=2.750" , • �' �'l.. 9700' —EST TOP OF CEMENT(07/16/06) 1�1 N11, 1111711 �111�1� 1111�� ? I-TUBING SEAL ASSEMBLY I e1•/111 114 4* t1, 111*21 9742' —19-5/8"X 3-1/2"TMJ PKR,ID=4.00" I 111/0.11 A64 BEHIND 11 01 11.1.E • 9803' I�3 1/2"PARKER X NIP,ID=2.75" CT LNR ITOP OF 7"LNR I-- 9813' *1 1111'11, .1�I,..4 11��1 10'.' 1 iir 9835' 1-13-1/2"PARKER X NIP, ID=2.75" I 14141. 111'1 111111 11111/14 .1111 110 3-1/2"TBG,9.3#,L-80, _0087 bpf, ID=2.992" —I 9869' .gyl1i 1404 9869' — 3-112"TAN WLEG, ID=2.992" /�l111 11111111 9877' HELMDTTLOGGED I 1441111 111441:4 11))11 11 111111' 9900' —1 EST BOTTOM OF CEMENT(07/16/06) 11� 1111 t1195/8"CSG,47#,L-80,NSCCID=8.681" —I 10085' 1111, 111 11, 11111 MILLOUT WINDOW(W-25A) 10100'- 10105' 2.74"PLOT HOLE WHIPSTOCK 10100' 1�14 1111 . v�.� 7"LNR,26#,L-80 U4S, .0383 bpf,ID=6.276" 10650' 111' �•�. X111`" PERFORATION SUMMARY 111111�1���V 11111111 ,. REF LOG: BHI MVVD GR/MPR ON 12103/09 X1111 1 ` 11111 • ANGLE ATTOP PERF 76° 10325' �11111111111� 111!1111 Note: Refer to Production DB for historical pert data 0 W X11 111111 S 11111 SIZE SPF INTERVAL Opn/Sqz DATE ����A��11 1.56" 6 10325- 10370 0 12/08/09 WO'. VI 1.56" 6 10390-10400 0 12/08/09 1111111111111 1.56" 6 10540- 10625 0 12/08/09 111111111 1.56" 6 10645-10905 0 12/08/09 iivo- 1-56" 6 10930- 10970 0 12/08/09 I PBTD(LOGGED 12/08/09) 1118T !.r:.1 1.56" 6 10990-11070 0 12/08/09 1.56" 6 11095-11105 0 12/08/09 12-3/8"LNR,4.6#, 13CR-80, .0039 bpf,ID=1.995" H 11220' 1.56" 6 11125-11145 0 12/08/09 1.56" 6 11160-11175 0 12/08/09 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/10/88 ORIGINAL COMPLETION 03/11/10 SWC/PJC SET LTTP(01/06/10) WELL: W-25A 12/09/09 NORDIC 2 CTD SIDETRACK(W-25A) 03/21/10 CJN/SV GLV C/O PERMIT No: 2091020 12/12/09 SV DRLG HO CORRECTIONS 06/01/10 RP/JMD DRLG DRAFT CORRECTIONS(12/21/09) API No: 50-029-21874-01-00 02/01/10 GF/JMD SET BKR KB STRADDLE(01/05/ 0)2/12/11 SWC/AGR GLV C/O(02/03/11) SEC 21,T11 N, R12E,980'FNL&1446'FEL 02/01/10 TTW/JMD SAFETY NOTE REV(01/21/10) 02/27/10 PJC SFTY NOTE UPDATE BP Exploration(Alaska) • 0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q 0 g - L 0 L., Well History File Identifier Organizing (done) ❑ Two -sided III 1111 I II III ❑ Rescan Needed 1 11111 I R AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. n' ❑ Maps: ❑ Greyscale Items: Other, No/Type: C V I `O' 1 ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: (/ BY: Maria Date: J 1 l /s/ r' Project Proofing III 1 1111 1111 BY: Date: / Js/ P /,, , d h Scanning Preparation � x 30 = lUa + i = TOTAL PAGES 70 (Count does not include cover sheet) BY: Date: 3 �� /s/ �l ' u III Production Scanning III 1111110 III I Stage 1 Page Count from Scanned File: IP (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO Pag g BY: Maria Date: ` 3 `/ /s/ (MP Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I I' IIIII I 11111 ReScanned I I III I BY: Maria Date: /s/ Comments about this file: Quality Checked III 1111 III 1111 III 10/6/2005 Well History File Cover Page.doc Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWeIIlntegrityCoordinator @bp.com] Sent: Tuesday, October 22, 2013 9:34 PM To: Wallace, Chris D (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity; AK, OPS WELL PAD W; Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: NOT OPERABLE: Producer W-25A(PTD#2091020) IA exceeded MOASP All, Producer W-25A(PTD#2091020) is currently Under Evaluation for an inner annulus MOASP excursion. Due to operational needs, the well will not be able to be brought online for further diagnostics. It has been reclassified as Not Operable until further testing can take place. Please call with any questions. Thank you, Laurie Climer ` BP Alaska - Well Integrity Coordinator GISCANNED j Gto ai welts GINorganization WIC Office: 907.659.5102 WIC Email: AKDCWeIIlntegrityCoordinator(a)BP.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, October 16, 2013 8:54 PM To: 'chris.wallace @alaska.gov'; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity; AK, OPS WELL PAD W; 'jim.regg @alaska.gov' Cc: 'AK, D&C DHD Well Integrity Engineer'; 'AK, D&C Projects Well Integrity Engineer'; Climer, Laurie A Subject: UNDER EVALUATION: Producer W-25A (PTD #2091020) IA exceeded MOASP All, Producer W-25A(PTD#2091020) inner annulus exceeded MOASP on Oct 13, 2013 with TBG/IA/OA= 330/2140/400 psi. At this time,the well is reclassified as Under Evaluation for further diagnostics. Plan forward: 1. DHD:TIFL 2. WIE: Further diagnostics as needed. 1 A copy of the TIO plot and wellbore schematic have been included for reference. Please call with any questions. Thank you, Laurie Climer BP Alaska - Well Integrity Coordinator Gw t�a G:o 'Welts V v x Orgarruat on WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator @BP.com 2 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator©bp.com] Sent: Wednesday, October 16, 2013 8:54 PM To: Wallace, Chris D (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity; AK, OPS WELL PAD W; Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Producer W-25A(PTD#2091020) IA exceeded MOASP Attachments: W-25A.pdf; W-25A TIO Plot 10-16-13.docx All, Producer W-25A(PTD#2091020) inner annulus exceeded MOASP on Oct 13, 2013 with TBG/IA/OA= 330/2140/400 psi. At this time, the well is reclassified as Under Evaluation for further diagnostics. Plan forward: 1. DHD:TIFL 2. WIE: Further diagnostics as needed. A copy of the TIO plot and wellbore schematic have been included for reference. Please call with any questions. Thank you, Laurie Climer SCANNED w 1 BP Alaska - Well Integrity Coordinator GMAT Gtonai Wells V r Y Organization WIC Office: 907.659.5102 WIC Email: AKDCWelIIntegrityCoordinator @BP.com 1 TREE=3-1/8"MCEVOY 5000# SAL MOTES: WELL ANGLE>70°@ 10310' *"•*2-3/8" WELLHEAD= MCEVOY CHROME LNR*".-* LT STRADDLE PKR DIFFERENTIAL ACTUATOR= OTIS PRESS RATING IS 2500 PSI. CONTACT WIE PRIOR TO KB.ELEV= 90.74' MIT-IA PER TTW(01/21/10) BF.ELEV= 54.54' L KOP= 2800' ' i 2066' I--10TIS SSSV LANDING NIP,ID=2.750" I Max Angle= 88°@ 10431' Datum MD= 10418' GAS LIFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2985 2985 4 MERLA DOME RM 16 03/20/10 13-3/8"CSG,68#,NT-80 BTRS,ID=12.415" H 2676' 4 6394 5837 44 MERLA DOME RM 16 03/20/10 3 8253 7272 37 MERLA DOME RM 16 03/20/10 2 9386 8180 36 MERLA SO RM 20 02/03/11 1 9604 8357 36 MERLA DM r RM 0 05/06/05 'BEHIND PATCH _ _ 9555' H3-1/2 LT STRADDLE PKR,ID=1.82"(01/06/10) I IIMinimum ID = 1.82" @ 9555' I I CI 3-1/2" LT STRADDLE PACKER A • 9624' H2.70"BLR DEPLOY SLV,ID=2.250" I 11 1t tj 9697' I--13-1/2"0115 SLIDING SLV,ID=2.750" I III 1 '�` r-t 9700' --I EST TOP OF CEMENT(07/16/06) I ��'1/ 11"t'1 1111 1471 011 01. *I .1 ? —{TUBING SEAL ASSEMBLY I 44411 I♦•p41 ta 4.∎A k17 y∎I' 9742' --I9-5/8"X3-1/2"TAN PKR,ID=4.00" I W•11 11►'rl •1•1■1•1 1.111 BEHIND /1 ►1, 11.1.1 11 e+1 It t. , 9803' H3-1/2"PARKER X NIP,ID=2.75" I CT LNR ITOP OF 7"LNR H 9813' 4./X01 11�11 r4,44. 111'1 041 64 1.I., 9835' H3-1/2"PARKER X NIP,ID=2.75" 1 •1.1/ It 11/4 1..114 ►1111111 100. 111'1 A1•/ ►111 3-1/T TBG,9.3#,L-80, .0087 bpf,ID=2.992" --I 9869' .wiV►111, 1i1'v,� 9869' H 3-1/2"TNV WLEG,ID=2.992" 1.41111 11111/ 987T H ELMD TT LOGGED??/7?/?? I 114111/ 111/114 11#1114 11111''-1 9900' HEST BOTTOM OF CEMENT(07/16/06) I 9-5/8"CSG,47#,L-80,NSCC,ID=8.681" H 10085' •111• 1111( ∎111 11111 MILLOUT WINDOW(W-25A) 10100'-10105' 2.74"PILOT HOLE WHIPSTOCK 10100' �111� 11111 4�1 1i I T'LNR,26#,L-80 U4S,.0383 bpf,ID=6.276" H 10650' I ;1111 1/��'. ►111`1 PERFORATION SUMMARY �1111111111111t REF LOG: BHI MWD GR/MPR ON 12f03/09 f 1111111 11111111 ANGLE AT TOP PERF: 76°@ 10325' 111111111111111 111!1111 ■ Note:Refer to Production DB for historical pert data .111114*.1 X111) SIZE SPF INTERVAL Opn/Sqz DATE e1*1*1*��41*1*1 1.56" 6 10325-10370 0 12/08/09 4.1.1'1.1.0'1 1.56" 6 10390-10400 O 12/08/09 111111111111111 1.56" 6 10540-10625 O 12/08/09 ��1�1�1�1�1�1�ii 1.56" 6 10645-10905 O 12/08/09 III*. 1.56" 6 10930-10970 O 12/08/09 IPBTD(LOGGED 12/08109) I 11187' !:�;�. 1.56" 6 10990-11070 O 12/08/09 .�. 1.56" 6 11095-11105 0 12/08/09 12-3/8"LNR,4.6#,13CR-80,.0039 bpf,ID=1.995" I 11220' 1.56" 6 11125-11145 O 12/08/09 1.56" 6 11160-11175 0 12/08/09 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/10/88 ORIGINAL COMPLETION 03/11/10 SWC/PJC SET LTTP(01/06/10) WELL: W-25A 12/09/09 NORDIC 2 CTD SIDETRACK(W-25A) 03/21/10 CJNJSV GLV C/O PERMIT No:82091020 12/12/09 SV DRLG HO CORRECTIONS 06/01/10 RP/JMD DRLG DRAFT CORRECTIONS(12/21/09) API No: 50-029-21874-01-00 02/01/10 GF/JMD SET BKR KB STRADDLE(01/05/ 08/12/11 SWC/AGR GLV C/O(02/03/11) SEC 21,T11 N,R12E,980'FNL&1446'FEL 02/01/10 TTW/JMD SAFETY NOTE REV(01/21/10) 02/27/10 PJC SFTY NOTE UPDATE BP Exploration(Alaska) Producer W-25A(PTD#2091020) 90 day TIO Plot 10/16/2013 Well:W-a 4.000- 3.000- Tbg —f—IA 2.000- —A—OA OOA 1 000 —4--000A On •-••M•••••-------------- 0720/13 07/27113 08/03/13 08/10/13 0817/13 08/24/13 08/31/13 09/07/13 09/14/13 09,21113 0928113 10/05/13 10/1213 • Page 1c 2' Regg, James B (DOA) � '' 2 0 - From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, February 06, 2011 7:24 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Oakley, Ray (PRA) Subject: OPERABLE: Producer W -25A (PTD #2091020) Tubing integrity restored - Passing TIFL All, q (024) Producer W -25A (PTD #2931 a TIFL on 2/6/11 after slickline changed out the OGLV. The passing test verifies tubing integrity has been restored. The well has been reclassified as Operable and may be placed back on production when convenient for operations. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 t' �a ' Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, January 22, 2011 11:21 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; . , I PS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; A OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations T-.m Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, R ' GPB East Wells Opt Engr; Oakley, Ray (PRA) Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); King, itney Subject: UNDER EVALUATION: Producer W -25A (PTD #2091020 Sustained Casing Pressure on the IA - POP to perform TxIA diagnostics All, Artificially lifted producer W -25A (PTD #20317.2 was classified as Not Operable during the shut down due to sustained casing pressure. The wellh: -d pressures were tubing /IA /OA equal to 1300/2100/500 psi on 01/14/2011. The well has been reclass ed as Under Evaluation so that it may be placed on production to perform diagnostics. The OA fluid level is near surfac•; please be careful of thermal expansion when placing W -01A on production. Plan forward: 1. DHD: TIFL 2. Well Integrity Engin: -r: Write work request to mitigate TxIA communication pending TIFL results A TIO plot and w *ore schematic have been included for reference. Please call !f:you have questions or concerns. Thank you, 2/7/2011 DATA SUBMITTAL COMPLIANCE REPORT 1/25/2011 Permit to Drill 2091020 Well Name /No. PRUDHOE BAY UNIT W -25A Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 21874 -01 -00 MD 11240 TVD 9013 Completion Date 12/10/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve)% Y DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR (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 g Gamma Ray 5 Blu 9020 11183 Case 1/26/2010 Mem DDL, Mem LEE, GR, CCL TE C Pds 19220 Gamma Ray 9020 11183 Case 1/26/2010 Mem DDL, Mem LEE, GR, CCL (Yog Production 1 Blu 20 9600 Case 1/26/2010 Mem PPL, PSP, GR, CCL, Pres, Temp, Gradio, Spin ED C Pds 19224 ✓Production 20 9600 Case 1/26/2010 Mem PPL, PSP, GR, CCL, Pres, Temp, Gradio, Spin Leak 1 Blu 20 9600 Case 1/26/2010 Mem LDL, PSP, GR, CCL, Pres, Temp, Gradio, Spin ED C Pds 19225/Leak 20 9600 Case 1/26/2010 Mem LDL, PSP, GR, CCL, Pres, Temp, Gradio, Spin t LIS Verification 9833 11240 Open 3/11/2010 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS III 1 D C Lis 19425 /I nduction /Resistivity 9833 11240 Open 3/11/2010 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS og Induction /Resistivity 25 Col 9851 11240 Open 3/11/2010 MD MPR, GR wog Induction /Resistivity 5 Col 9851 11240 Open 3/11/2010 TVD MPR, GR ,` i Gamma Ray 25 Col 9851 11240 Open 3/11/2010 MD GR E D C Lis 19511+ / Gamma Ray 9010 11184 Case 4/9/2010 LIS Veri, GR, CCL D C Directional Survey 10095 11240 Open pt Directional Survey 10095 11240 Open DATA SUBMITTAL COMPLIANCE REPORT 1/25/2011 Permit to Drill 2091020 Well Name /No. PRUDHOE BAY UNIT W -25A Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 21874 -01 -00 MD 11240 TVD 9013 Completion Date 12/10/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION • Well Cored? Y / Daily History Received? N Chips Received ? - -/-N Formation Tops '/ N Analysis "7 Received? Comments: J z � Compliance Reviewed By: Date: t�..� l/ • STATE OF ALASKA RECEIVED ALASKA "IL AND GAS CONSERVATION COMMIS ON APR 1 2 2010 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate 0 owiask01 &GasCpn$.CommtSSIO Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waived] Time Extension ❑ At1choraae Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: k Permit to Drill Number: Name: Development 0 Exploratory ❑ 209 -1020 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ API Number: Anchorage, AK 99519 -6612 50- 029 - 21874 -01 -00 8. Property Designation (Lease Number) : \, 9. Well Name and Number: ADLO- 028263 \ PBU W -25A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11240 feet Plugs (measured) None feet true vertical 9013.02 feet Junk (measured) None feet Effective Depth measured 11187 feet Packer (measured) 9742 true vertical 8986.2 feet (true vertical) 8467 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2676 13 -3/8" 68# L -80 SURFACE - 2676 SURFACE - 2676 4930 2270 Intermediate 10085 9-5/8" 47# N -80 SURFACE - 10085 SURFACE - 8744 6870 4760 Production Liner 550 7" 26# N -80 10650 - 10100 8524 - 8756 7240 5410 Liner 1596 2 -3/8" 4.7# 13CR80 9624 - 11220 8372 - 9003 Perforation depth: Measured depth: SEE ATTACHED _ - _ — True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 3 -1/2" 9.3# L -80 SURFACE - 9896 SURFACE - 8591 Packers and SSSV (type, measured and true vertical depth) 9- 5/8 "X3 -1/2" TIW PKR 9742 8467 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 343 ,l 324 46 298 Subsequent to operation: 724 / 981 190 300 14. Attachments: X Well Class after work: Copies of Logs and Surveys Run V Exploratory Development El Service ❑ Daily Report of Well Operations X Well Status after work: Oil El Gas ❑ WDSPL ❑ GSTOR ❑ WAG ❑ GINJ ❑ WINJ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prej1 / Title Data Management Engineer Signature / Phone 564 -4944 Date 4/12/2010 FUT III 10-404 - Cvibed 7/2009 Submit Of ;gild! Only RaDMS APR 13 20105 1 - ----- 9 4. Y• /3./c, YC:"4, W -25A 209 -102 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Tor Tvd Depth Base W -25A 12/8/09 PER 10,325. 10,370. 8,880.03 8,887.68 W -25A 12/8/09 PER 11,160. 11,175. 8,974.86 8,980.92 W -25A 12/8/09 PER 11,125. 11,145. 8,962.94 8,969.4 W -25A 12/8/09 PER 10,990. 11,070. 8,941.2 8,950.41 W -25A 12/8/09 PER 11,095. 11,105. 8,955.07 8,957.44 W -25A 12/8/09 PER 10,645. 10,905. 8,908.71 8,932.98 W -25A 12/8/09 PER 10,540. 10,625. 8,899.23 8,906.48 W -25A 12/8/09 PER 10,390. 10,400. 8,889.52 8,890.15 ID W -25A 12/8/09 PER 10,930. 10,970. 8,935.47 8,938.97 W -25A 12/13/09 BPS 9,597. 9,600. 8,350.49 8,352.92 W -25A 12/15/09 BPP 9,597. 9,600. 8,350.49 8,352.92 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE I • W -25A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/2/2010T /I /0= 1800/50/650 Acid Job (scale treatmentLSet up equipment for acid treatment down TBG. Awgers continued on 04 -03 -10 4/3/2010; T/I/0= 1550/450/500 Temp =S /I Load IA (PreScale Treatment) Pumped 2 bbl j neat meth spear followed by 613 bbls crude down IA. Tags ung on WV,IA. WV= closed; IA,OA =open, ASRC on well upon departure, operator notified. FW HP's= 1850/450/680 4/3/2010 /I /O= 1800/1500/650 ( Acid Treatment) Pump 6 bbls neet meth down FL to FP. Swap to TBG and Pump 12 bbls 12.3% Acid followed by 5 bbls neet meth then 165 bbls dead crude to spot Acid. RDMO. FWHP= 800/1700/650 / wing =shut / ssv= open / swab =shut / master= open / IA and OA open to gauges. Operator notified. 4/3/2010T/I/0= 800/1360/520. Temp =S1 Bleed IAP to LP (Pre -FB), AL SI @ casing ,valve, ALP =1830 psi. Acid pickle flow back completed. Initial IA FL @ 9386' Sta 1 #2 SO (575 bbls). Bled IAP from 1360 psi to 450 psi in 2 -1/2 hrs to W -26 L -P !flowline (online). During IA bleed the OAP decreased 60 psi to 460 psi. Monitor for 30 mins, IAP unchanged, IA FL unchanged. Final WHPs= 800/450/460. :**Note unable to open swab to monitor TP on W-25, ASRC test unit rigged to W- 25 for Acid flow back, last known TP was @ 800 psi. LRS moving in to load IA. 1SV, WV= Closed. SSV, MV =Open. IA, OA =OTG. W -26 SV= Closed. ASRC Test Unit #2 Assist LRS Divert well flow tubing treatment, 4/3/2010 :ASRC g S /I, LRS fluid pack I /A, Inlet W -27, Outlet W -27, ** *Job in progress * ** 4/4/2010' Perform Bullhead acid stimulation. 112% HCL titration was 12.4% 9:1 Mud Acid titration was 9.2 %, HF is 1.1% 4/4/20101ASRC Test Unit #2, Assist Schlumberger acid treatment, divert well start acid ' flowback monitor pH, Inlet W -25, Outlet W -27, ** *Job in progress * ** 4 /5 /2010ASRC Test Unit #2, Continue acid treatment flow back, Inlet W -25, Outlet W -27, ** *Job in progress * ** 4/6/2010 ASRC Test Unit #2, Continue acid flowback, monitor pH, Inlet W -25, Outlet W-27, ** *Job in progress * ** 4 /7 /2010¢ASRC Test Unit #2, Complete acid flowback, stabilize well, Complete 12 hour test, Start R/D, Inlet W -25, Outlet W -27, ** *Job in progress * ** s 1 4 /8 /2010ASRC Test Unit #2, RDMO, S/B for rig move off next location, Move unit, Inlet W- =25, Outlet W -27, ** *Job complete * ** I l 4/10/2010:TIO= 300/1320/480. Temp =Hot. TIFL Passed. (Post acid job). On line with AL. 1 SI, stack out TBG. Initial IA FL @ 9386' (so). Bled IAP down flow line to 530 psi !in 2.5 hrs. SI bled, monitor for 45 mins with no change in pressures or IA FL. Final W HPs= 1780/530/400 E ** Job complete ** P.O.P. SV,WV =C. SSV,MV =O. IA,OA =OTG. NOVP FLUIDS PUMPED BBLS 12 12.9% ACID 14 60/40 26 Total TRF-E = 3 -1/8 "MCEVOY 5000# SAFET ES: WELL ANGLE> 70° @ 10310' *** 2.318" WELLHEAD = MCEVOY CHROM NR *** LT STRADDLE PKR DIFFERENTIAL ACTUATOR = OTIS J IIID DRAFT W .2 5q PRESS RATING IS 2500 PSI. CONTACT WIE PRIOR TO KB. ELEV = 90.74' MIT -IA PER TTW (01/21/10) BF. ELEV = 54.54' KOP = 2800' 1 1 • I 2066' 1 -IOTIS SSSV LANDING NIP, ID = 2.750" I Max Angle = 88° @ 10431' Datum MD = 10418' GAS LIFT MANDRELS DatumTVD= 8800'SS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 2985 2985 4 MERLA DOME RM 16 03/20/10 113 -3/8" CSG, 68#, NT -80 BTRS, ID = 12.415" H 2676' 4 6394 5837 44 MERLA DOME RM 16 03/20/10 3 8253 7272 37 MERLA DOME RM 16 03/20/10 2 9386 8180 36 MERLA SO RM 20 03/20/10 1 9604 8357 36 MERLA DMY *_ RM 0 05/06/05 *BEHIND PATCH 9555' 1 - 1/2" LT STRADDLE PKR, ID = 1.82" (01/06/10) 1 Minimum ID = 1.82" @ 9555' ...T. ...1.r. 3 -1/2" LT STRADDLE PACKER �A 1111 9624' H2.70" BLRDEPLOY SLV, ID= 2.250" I • 1+ i L 9697' H3 -1/2" OTIS SLDING SLV, ID = 2.750" f. ' *fit . • 9700' — EST TOP OF CEMENT (07/16/06) I N/14. 1 1 , 4 441 141 1 • ? —ITUBING SEAL ASSEMBLY 1 d ►1 +* CI tO ea 9742' H9-5/8" x 3 - h 12 " TIW PKR, ID = 4.00" I / 1 11 ► 0 1144 14 k4i BEHIND 4 1 t 1 ' 9803' 1 PARKER X NIP, ID = 2.75' I TOP OF 7" LNR I 9813' � 4. 1 1�1 (� 1 CT LNR 1 11 0 �t/ 1� �;!* 9835' 1- 13 -1/2 " PARKER X NIP, ID = 2.75" I : 1:1. 3 -1/2" TBG, 9.3 #, L -80, .0087 bpf, ID = 2.992" 1—I 9869' 11 444'4'4 � 9869' 1 TM! WLEG, ID = 2.992" 1 0 1 1 14 1 i X 1 /1 I 9877' H ELMD TT LOGGED ??/??/?? I '4 X 4 1 4 1 1 4 1 1 10+ o 1 / 111 1 9900' I — I EST BOTTOM OF CEMENT (07/16/06) I A*. 44 114141 1 9 - 5/8" CSG, 47 #, L - 80, NSCC, ID = 8.681" H 10085' 1 !1 1 1 1 1 1 ] 444 144 X14. 111 MILLOUT WINDOW (W - 25A) 10100' - 10105' 111 111 I PILOT HOLE WHIPSTOCK I—I 10100' ∎1 44 1 7" LNR, 26 #, L -80 IJ4S, .0383 bpf, ID = 6.276" I 10100 ° ? .. ■■••iiii 1111111 ` PERFORATION SUMMARY 4 REF LOG: BHI MWD GR/MPR ON 12/03/09 ∎ 1111111 t ANGLE AT TOP PERF: 76° @ 10325' •1 4.1 ` Note: Refer to Production DB for historical perf data 4,444 11 SIZE SPF INTERVAL Opn /Sqz DATE 4:0.1.4.0.+ •1 1.56" 6 10325 - 10370 0 12/08/09 1 1 1 1 1 4 1 1 1 1 1 1 1 1 ) 1.56" 6 10390 - 10400 0 12/08/09 W.1.1A1.1 1.56" 6 10540 - 10625 0 12/08/09 al- 1.56" 6 10645 - 10905 0 12/08/09 I PBTD (LOGGED 12/08/09) 1 11187' !s+�" 1.56" 6 10930 - 10970 0 12/08/09 ` fti 1.56" 6 10990 - 11070 0 12/08/09 1.56" 6 11095 - 11105 0 12/08/09 12 -3/8" LNR, 4.6 #, 13CR -80, .0039 bpf, ID = 1.995" I—I 11220' 1.56" 6 11125 - 11145 0 12/08/09 1.56" 6 11160 - 11175 0 12/08/09 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/10/88 ORIGINAL COMPLETION 02/27/10 PJC SFTY NOTE UPDATE WELL: W -25A 12/09/09 NORDIC 2 CTD SIDETRACK (W -25A) 03/11/10 SWC /PJC SET LTTP (01/06/10) PERMIT No: 2091020 12/12/09 SV DRLG HO CORRECTIONS 03/21/10 CJN/SV GLV C/O API No: 50- 029 - 21874 -01 -00 12/21/09 ? /JMD DRLG DRAFT CORRECTIONS SEC 21, T11 N, R12E, 980' FNL & 1446' FEL 02/01/10 GF /JMD SET BKR KB STRADDLE (01/05/10) 02/01/10 TTW /JMD SAFETY NOTE REV (01/21/10) 1 BP Exploration (Alaska) 04/05/10 Schhimberger NO. 5495 Alaska Data & Consulting Services Company: State of Alaska 2525 °emboli Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 95503.2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 9 Log Description Date BL Color CD P2-31A BBKA -00014 CEMENT BOND LOG 00 / 9 , d 03/16/10 1 1 5-134 AP30 -00083 INJECTION PROFILE UI@i cd( — I')'Sf!i '157 a 03/26/10 1 1 P2 -31A _ 81 4 8 -001 01 USIT - }U�j '�- -it /D a,..' 11 03/27/10 1 1 03 -22 B5JN -00047 PRODUCTION PROFILE / f /'3 T'/ 03/28/10 1 1 17 -07B BD88 -00007 MEM PRODUCTION PROFILE - Q -4---b.) .21 /43 996( 03/28/10 1 1 r 17 -05 B3S0 -00052 PRODUCTION PROFILE / A r 03/29/10 1 1 17-11 B3S0 -00053 PRODUCTION PROFILE / 2f � a / s �fr i g 03/30/10 1 1 1;j � a qr / 03 -22 _ B5JN -00047 RST /JEWELRY LOG ( 7 i 03/30/10 1 1 14 -32 BAUJ -00012 MEM PRODUCTION PROFILE / 1 / 4 :419 03/31/10 1 1 W -25A AWYZ -00004 CH EDIT PDC (DDL) ,34 /) /V6 /,/ 12/08/09 1 - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gembeil Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 \I / RECEIVED 13 APR 0 (i2010 Make ON 14 , Com Commission Anchorsoo INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: W -25A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print — GR Directional Measured Depth Log (to follow) 1 color print — MPR/Directional TVD Log (to follow) 1 color print — MPR/Directional Measured Depth Log (to follow) s LAC Job #: 2902041 Sent by: Donna Mo s Date: 03/ Received by: Date: , j filar r PLEASE ACKNOWLEDGE RECEIPT B aSTIN , TU G OR FAXING YOUR COPY FAX: (907) 267 -6623 Baker Hughes INTEQ 7260 Homer Drive 0 —/ r�- BAKER Anchorage, Alaska 99518 HUGHES Direct: (907) 267 -6612 INTEQ FAX: (907) 267 -6623 BAKER HVGHES Baker Atlas PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION (ALASKA) INC COUNTY NORTH SLOPE BOROUGH WELL NAME W -25A STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 3/3/2010 THIS DISTRIBUTION LIST AUTHORIZED BY: Donna Moss SO #: 2902041 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2 -1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OFALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By: BAKER ATLAS -PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: D /o Page 1 of 1 • Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble @bp.com] Sent: Tuesday, February 02, 2010 3:08 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU W -25A / PTD # 209 -102 Hi Art, Please reference the following well: Well Name: PBU W -25A Permit #: 209 -102 API #: 50- 029 - 21874 -01 -00 Top Perf MD: 10325' Bottom Perf MD: 11175' This well began Production on January 25, 2010 Method of Operations is: Gas Lifted Date of Test: 01/28/10 Hours Tested: 6 24 -Hour Rate / Oil-Bbl: 895 24 -Hour Rate / Gas -Mcf: 692 24 -Hour Rate / Water -Bbl: 4 Test Rate / Oil -Bbl: 224 Test Rate / Gas -Mcf: 173 Test Rate / Water -Bbl: 1 Choke Size: 176 Gas -Oil Ration: 773 Flow Tubing Pressure: 320 Casing Pressure: 1,200 Oil Gravity -API: 26 2/3/2010 NO. 5378 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 4 Log Description Date BL Color CD • MPJ-19A B581-00020 USIT 1 'k5 1'46 i '. . 12/19/09 1 1 W-25A AXBD-00063 MEM LDL 0, - it) ? ak b A 12/14/09 1 1 W-25A AXBD-00061 MEM PROD PROFILE tiC6 (,) 1 4 1-1 t .) 12/14/09 1 ' 1 07-26 BALL-00007 RST j '6:3 ""/WV 1 -74:l , ... 12/08/09 1 1 X-10 , BALL-00001 PRODUCTION PROFILE ir - b 1 fl 11/30/09 1 1 X-13A BALL-00002 PRODUCTION PROFILE - () (,9 6" 1 3 EVIs 12/02/09 : 1 1 GC-2E B5JN-00027 PRESS/TEMP SURVEY v2 d„, Lill- -6 Lb j el Q0 _ 12/08/09 1 . 1 B-16A AZCM-00049 GLS .- to D') , i c l 12/04/09 1 1 > W-25A AWYZ-00004 MEM DDL - B5JN-00029 PRODUCTION PROFILE - C31 I 12/08/09 1 12/10/09 1 1 Z-16 1 X-32 B5JN-00024 , PRODUCTION PROFILE ,'3 -, (,,,, I p 12/04/09 1 1 .. 110 X-25 L-210 AYKP-00058 PRODUCTION PROFILE are../-03g / 4a 11/29/09 1 1 e anAi_ ei B2NJ-00043 MEM INJECTION PROFILE crr. -festo 1 1 3 12/01/09 1 ' S-218 09AKA0176 . 0H MWD/LWD EDIT ed f)5 0 q 1 9 _ 10/12/09 2 1 L-222 09AKA0148 OH MWD/LWD EDIT ( y - J -p, o 7 1 1 9 19,0 _ 11/03/09 2 1 2-08/K-16 AZCM-00046 RST i VII -7.010q 1 1 9 ri,, ..... , 10/31/09 1 1 11-10 AP3Q-00066 RST ( zTe. 1755 15 - / i, ' )ri S 11/01/09 1 1 • , . . - , . - . . - . . - . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 0 BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 ■n. ' \NI +. (? . ' ' 115 NO. 5378 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 - 2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD MPJ -19A B581-00020 USIT a - ► 12/19/09 1 1 W -25A AXED -00063 MEM LDL ..5alegiy!_` jp)M- 12/14/09 1 1 W -25A AXBD -00061 MEM PROD PROFILE a a -. • JG / aO 12/14/09 1 1 07 -26 BALL -00007 RST . -4, , 12/08/09 1 1 X -10 BALL -00001 PRODUCTION PROFILE 11/30/09 1 1 X -13A BALL -00002 PRODUCTION PROFILE a - (%)(,, •S' i 9.4 "' 12/02/09 1 1 GC -2E B5JN -00027 PRESS/TEMP SURVEY a A 12/08/09 1 1 B -16A AZCM -00049 I , ��L - • , 12/04/09 1 1 W -25A AWYZ -00004 MEM DDL . .AL'nbif! _ 12/08/09 1 1 Z -16 B5JN -00029 PRODUCTION • ROFILE Yalu 12/10/09 1 1 • X -32 B5JN -00024 PRODUCTION PROFILE ■ - MEM 12/04/09 1 1 X -25 AYKP -00058 IJ :Te1r74•itI :1∎I 111 ; ► �ra. 11/29/09 1 1 L -210 B2NJ -00043 MEM INJECTION PROFILE ,,� -- • • 12/01/09 1 1 S -218 09AKA0176 C�7:1�,1' h 10/12/09 2 1 L -222 09AKA0148 OH MWD/LWD EDIT •' - 11/03/09 2 1 2- 08/K -16 AZCM -00046 12311111.kr -0Q 10/31/09 1 1 11 -10 AP3Q -00066 EREMi kt � rell.1.1 11/01/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambelt Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 Cf5 NO. 5378 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Mtn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 4 Log Description Date BL Color CD MPJ-19A B581-00020 USIT 1 - (4% 12/1 9/09 1 1 W-25A AX5D-00063 MEM LDL a'50, - /0 D 5— 12/14/09 1 1 (°°............. W-25A X-10 AXBD-00061 MEM PROD PROFILE . 4 ...- • - ,. . • 12/08/09 1 1 BALL-00007 RST • C n i ll I I I I M ' . BALL-00001 PRODUCTION PROFILE #0 - ••• . 12/i 4/09 1 11/30/09 1 1 07-26 1 X-13A BALL-00002 PRODUCTION PROFILE ' - 0 (9,S I Xrif 12/02/09 1 ' 1 GC-2E B5JN-00027 PRESS/TEMP SURVEY yi e„. 6'4- -6 ifj 1 el 4 90 4 A 12/08/09 1 1 8-16A AZCM-00049 GLS n --. 1•0 )-- 7 e t • / ') 2ie) 12/04/09 1 1 W-25A AWYZ-00004 MEM DDL ' CL" /6 / IQ 4 12/08/09 ' 1 1 Z-16 B5JN-00029 PRODUCTION PROFILE I - ry I I4) 1 12/10/09 1 1 X-32 B5JN-00024 PRODUCTION PROFILE 113 -/ 4,9 I p2 12/04/09 1 1 • X-25 AYKP-00058 PRODUCTION PROFILE f .w_p3c, 1 ,.. 11/29/09 B2NJ-00043 MEM INJECTION PROFILE vi.e. 426,. 02_3 12/01/09 1 1 1 L-210 ..-01 1 S-218 09AKA0176 OH MWD/LW0 EDIT ‘)(59 —09 q 1 ci 10/12/09 2 1 L-222 - 09AKA0148 OH MWD/LWD EDIT ( y Oucl,..— I 19 i q_p_t5 11/03/09 2 1 2-08/K-16 AZCM-00046 RST . 1 Inc -DOC( i 1 9riy 10/31/09 1 1 , 11-10 AP30-00066 RST ( yta 1755 i tc - jai :.....)." 11/01/09 1 1 . . , , . .. ' _ . . . , _ - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: Illp BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 (5 • Page 1 of 1 Schwartz, Guy L (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWelllntegrityEngineer @BP.com] Sent: Wednesday, January 13, 2010 3:07 PM To: Schwartz, Guy L (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: W-25A Status 209402) Attachments: W -25A Patch -LTP Proceudre.doc; W- 25A.pdf Guy, Please see the `attached program for a patch /LTP for W -25A (PTD #2091020). The program explains the history of the well including the failed test of the liner lap and the possible cause of TxIA communication. To return the well to production, a combination patch / liner top packer assembly was set on 01/05/09 and passed a MITIA. The well is currently classified as Operable. A draft wellbore schematic has been included for reference. Please note that the patch /LTP is not yet represented in the schematic. Please let me know if there are any other questions. Thank you, Anna Dube, 1n .�. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659 -5102 Pager: (907) 659 -5100 x1154 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, January 13, 2010 1:31 PM To: NSU, ADW Well Integrity Engineer Subject: W -25A Status (PTD 209 -102) Torin, Do you know the status of the recent sidetrack W -25A? It was completed on 12/10/09. It failed the initial pressure test of the liner lap while the CTD rig was there. A liner top packer was not set so wasn't sure if this was a tubing leak issue or the liner top. Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 1/13/2010 • Results of LDL A LDL was performed on 12/14/09 and it was determined the leak in the tubing is at 9614' ELMD (TOL at 9623' ELMD). This is approximately 11' above the liner top and corresponds to the location of the wash out on the PH6 pipe (mentioned above). A combination straddle /LTP assembly will be run to fix both the TxIA communication and the leaking liner lap. For questions or comments regarding this procedure, please call Carolyn Kirchner at 907 - 564 -4190 (W), 907 - 227 -6169 (C) or Josh Allely at 907 - 350 -7362 (C), 907 - 564 -5732 (W) or Dan Robertson at 907 - 564- 5546(W), 346 -3714 (H) or 529- 5818(C). cc: Well File PLEASE NOTE We will be running a special clearance 35 KB packer straddle assembly. The OD of these packers is 2.74" (turned down from 2.78 "). Please ensure the OD of the assembly brought to location is not greater than 2.75" (ID of x- nipple at 2065'). It is also important to note that the pressure differential of a 35 KB packer is 2500 psi. Due to this limited differential, we will not be performing a MIT -IA; instead, we will perform a MIT -T followed by a CMIT -TxIA. This will show that the well can be made operable without putting undue stress on the straddle assembly. Also note that all depths in this procedure are referenced to the SLB GR/CCL log [12/08/09]. This is approximately 6' off of the tubing tally. The critical length in this straddle assembly is the distance from the "no -go" above the seal assembly to the upper element: this distance must be at least 26' to ensure the upper element does not set inside the GLM. Please double check this length prior to running assembly. (The attached completion schematic has this length at 27.5'). Procedure: 1. MIRU SL and Fullbore 2. Drift well with a 2.74 drift that is representative of the straddle assembly. It is probably sufficient to simulate the length and dimensions of a special clearance 35 KB Packer. 3. Set straddle assembly with a memory firing sub (either SLB E -Fire or HES ETD). Please choose the firing sub that maximizes the chances of a successful set. Assembly will need to be jarred into place to ensure the stinger assembly has "no -go'd" on top of the deployment sleeve. a. Be very careful when running assembly through the SSSV at 2065'. The OD of the straddle assembly is very close to that of the nipple profile. 4. Set a LTTP (standing valve) in the top of the straddle assembly and perform a MIT -T to 2500 psi. by • Cr i) .4, f.•. 2ci - / 0 Z i 400 To: Jerry Bixby /Clark Olsen Date: 12/21/2009 GPB Well Ops Team Leaders From: Carolyn Kirchner, PE PECT: PBD4P2935 Josh Allely, Wells Group PE Est. IOR: 1500 Subject: W -25A Patch /LTP Est. Cost: $40K Attached is a program to prepare W -25 for production that includes the following major steps: 1 S Set LTP /Patch Assy (see attachment) 2 F MIT -T and CMIT -TxIA to 2500 psi (combined operation with SL). Current Status: Gas lift producer Last Test N/A Max Deviation: 88 degrees @ 10,431' MD Perf Deviation 34 degrees @ 10,256' MD Minimum ID: 1.941" @ top of 2 -3/8" liner Last Downhole Op: 12/14/09 Memory LDL run from 9604' SLM (LTP) to surface Last Drift: 12/08/09 Tag TD at 11,187' DD while perfing Last Tag: 12/08/09 Tag TD at 11,187' DD while perfing Latest H2S Value: 07/08/08 16 PPM SBHP /SBHT: 01/22/08 For W -25: 3617 psi @ 230 °F Job Objective: To repair the source of TxIA communication that developed while the rig was on the well completing a CTD sidetrack. This will also isolate the leaking liner lap. Background: While sidetracking well W -25 to its new location of W -25a with CTD, TxIA communication was established. Prior to the CTD ST, the tubing and IA were cemented to 9700' MD in the IA and 9851' MD in the tubing on 07/16/06 below the sliding sleeve in the original well. The 9- 5/8 "x3 -1/2" packer has been cemented in the past, but the condition of this cement is unknown. While trying to land the 2 -3/8" liner on 12/6/09 there was some difficulty reaching bottom and the liner was reciprocated across this sliding sleeve, possibly opening the port to create a flow path from the reservoir into the IA. Once the liner was landed, it was cemented into place. Top of liner and cement is at 9624' DD which is above the sliding sleeve. The liner lap test failed at 19% pressure Toss in 30 minutes with the tubing and IA tracking. While drilling, there was a washout of the CT PH6 pipe that created a hole of 3/8" diameter. It is possible that this was able to jet a hole through the tubing. The calliper report from 6/21/09 of the tubing shows no greater than 53% penetration and no significant wall loss in the pipe. Maximum deterioration of the tubing is concentrated from approximately 3200 -5300' MD. a. If the MIT -T fails, attempt to reset the LTTP. If it fails again, it will be necessary to pull and re -run the straddle assembly. b. If the MIT -T passes, with the tubinci still pressured up, perform a CMIT -TxIA to 2500 psi. Maintaining pressure on the tubing will limit the stress put on the straddle assembly. c. If the CMIT fails, it will be necessary to re -run the straddle assembly. 5. 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Man: OD ID Length I 1.15' $ 9596' .30' U 35' KB" Upper Straddle Packer 3" GS Fishing Neck Up 2.74" 1.87" 4.67' 2 3/8" STL Pin Down 15K Shear Release 1111 H819633501 3.22' 1 ■ I 20.00 2 3/8" STL B x P Spacer Nipple 2.74" 1.995" 20.00' INN T T w .80' mum Mill 35 "KB" Lower Straddle Packer LI] 23/8 "STLBxP 15K Shear Release 2.74" 1.825" 5.32' H819633501 (5) 10-32 J 4600#'s (1 Shear) 1111 3.50 (1)',' - 20 @ 1415#'s (2 Shear) 1 Shear Ring Adapter (internal) . (9) 10-32 CP 8280#'s shear 9623' 1 TOL -T2.00' WLEG No-Go to WLEG 2 318" STL Box 2.38" 1.84" 2.00' 1 w/ 2.25" OD Seal Unit DHMneMue are Poi reMena only. Exact tempo TEO. 0 STATE OF ALASKA 111, REPFIVED ALASKA OIL AND GAS CONSERVATION COMMISSION ; 0 1 2010 WELL COMPLETION OR RECOMPLETION REPORT AND X6: C ars, Cl mmiss o T la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended lb. Well Class: A, , ^r 20AAC 25.105 20AAC 25.110 ® Development 0 5xploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions One ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Com Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 12/10/2009 209 - 102 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 12/3/2009 50 029 - 21874 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 12/5/2009 PBU W -25A 980' FNL, 1446' FEL, SEC. 21, T11N, R12E, UM 8. KB (ft above MSL): 91 15. Field / Pool(s): Top of Productive Horizon: 1085' FSL, 5007' FEL, SEC. 16, T11 N, R12E, UM GL (ft above MSL): 53.24' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 547' FSL, 61' FEL, SEC. 17, T11 N, R12E, UM 11187' 8986' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD):. 16. Property Designation: Surface: x- 611789 y - 5959273 Zone- ASP4 11240' 9013' ADL 028263 & 028262 TPI: x- 608193 y- 5961285 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 607869 y 5960743 Zone- ASP4 None 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): 18. Directional Survey: El Yes ❑ No (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD DIR, GR 10100' 8756' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE ToP BOTTOM ' TOP I BOTTOM SIZE CEMENTING RECORD - PULLED 20" Insulated Conductor Surface 110' Surface 110' 8 cu vds Concrete 13 -3/8" 68# L -80 Surface 2676' Surface 2676' 17 -1/2" 1920 cu ft CS III. 1922 cu ft CS II 9 -5/8" 47# N -80 Surface 10085' Surface 8744' 12 -1/4" 1528 cu ft Class 'G'. 585 cu ft Class 'G' 7" 26# N -80 10650' 10100' , 8524' 8756' 8 -1/2" 304 cu ft Class 'G' ' 2 -3/8" 4.7# 13Cr80 / L - 9624' 11220' 8372' 9003' 3" 45 cu ft Class 'G' 24. Open to production or injection? ® Yes ❑ No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 1.56" Gun Diameter, 6 spf 3 -1/2 ", 9.3#, L -80 9869' 9742' / 8467' MD TVD MD TVD 10325' - 10370' 8880' - 8888' 26, ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10390' - 10400' 8890' - 8890' 10540' - 10625' 8899' - 8906' DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED 10645' - 10905' 8909' - 8933' 2500' Freeze Protected w/ 23 Bbls of Diesel 10930' - 10970' 8935' - 8939' 10990' - 11070' 8941' - 8950' 11095' - 11105' 8955' - 8957' 11125' - 11145' 8963' - 8969' 11160' - 11175' 8975' - 8981' 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL -BBL: GAS-MCF: WATER -BBL: OIL GRAVITY-API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. Cu ,r LLT"1ON. t None 141;91Th I RBDMS __ ► > . IeN - 8 20 10 �'� Form 10-407 Revised 07/2009 CONTINUED ON REVERSE Submit Original Only 1 ' il' /a E� " L ( /) I 29. GEOLOGIC MARKERS (List all formations and Mrs encountered): 30.ORMATION TESTS NAME MD TVD Well Tested? ❑ Yes 0 No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Shublik 10108' 8762' None Eileen 10259' 8856' Sadlerochit / Zone 4 10321' 8879' Formation at Total Depth (Name): Ivishak / Zone 4 10321' 8879' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. 7 tr-„ Signed: Terrie Hubble " 'MU 6( Q Title: Drilling Technologist Date: VC1 "� Iv PBU W - 25A 209 - 102 Prepared By Name/Number. Terrie Hubble, 564 - 4628 Well Number Permit No. / Approval No. Drilling Engineer: Ron Phillips, 564 -5913 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: 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 and Ground Level elevation in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 07/2009 Submit Original Only • BP EXPLORATION ! Page 1 of 13 Operations Summary Report Legal Well Name: W -25 Common Well Name: W -25 Spud Date: 10/10/1988 Event Name: REENTER +COMPLETE Start: 11/18/2009 End: 12/10/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/10/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 11/27/2009 00:00 - 00:30 0.50 MOB P PRE WAIT ON SECURITY. 00:30 - 01:00 0.50 MOB P PRE MOVE RIG FROM Y PAD TO THE SPINE ROAD. PJSM WITH SECURITY REGARDING MOVING THE RIG. 01:00 - 04:35 3.58 MOB P PRE MOVE RIG FROM Y PAD TO THE SPINE ROAD. 04:35 - 06:15 1.67 MOB P PRE TURN ONTO SPINE ROAD & HEAD WEST TOWARDS W PAD. 06:15 - 06:45 0.50 MOB P PRE CREW CHANGE. HOLD PJSM TO DISCUSS CONTINUED MOVE. DISCUSS PROJECTS TO BE PERFORMED ON RIG DURING THE MOVE. 06:45 - 10:30 3.75 MOB P PRE CONTINUE TO MOVE RIG ALONE SPINE ROAD, WITH ESCORT. RIG ON LOCATION. 10:30 - 13:00 2.50 MOB P PRE PARK RIG. PREP WELL HEAD AREA FOR HERCULITE AND RIG MATS. 13:00 - 17:00 4.00 BOPSUF P PRE CHANGE BOP RAMS IN CELLAR. BOPS TO BE RE- CONFIGURED FOR 2" COIL. 17:00 - 18:00 1.00 MOB P PRE SPOT RIG OVER WELL. 18:00 - 18:45 0.75 BOPSUF P PRE CIO W/ DAY CREW. PJSM REGARDING RU HANDY BERM & RU OA GAUGE HOSE. PERFORM WALK AROUNDS & SPILL CHAMPION. ACCEPT RIG AT 1800. 18:45 - 20:00 1.25 BOPSUF P PRE RU HANDY BERM & WEATHER PROOF THE CELLAR. CHECK OA FLANGE BOLTS - TIGHT. RU OA GAUGE HOSE. SPOT 20:00 - 20:30 0.50 BOPSUF P PRE PJSM REGARDING NU BOPE. 20:30 - 00:00 3.50 BOPSUF P PRE ND TREE CAP. NUB P & CHOKE LINE. NU 7- 1/16 "x3 -1/8" PQOL RU LUBRICATOR. SECURE STACK. GET BOP MEASUREMENTS. SPOT CUTTINGS BOX. SPOT TIGER TANK. SPOT OFFICE CAMP. SPOT WELDING SHOP. INSTALL 2" E -COIL. RU HARDLINE INSIDE REEL. RU IA CRASH FRAME & SLB TRANSDUCERS. 11/28/2009 00:00 - 01:00 1.00 BOPSUF P PRE FILL STACK & SHELL TEST BOPE - NO LEAKS. CONTINUE TO RU INNER REEL HARDLINE. 01:00 - 06:00 5.00 BOPSUF P PRE TEST BOPE PER AOGCC REGS, 250PSI /3500PSI - PASS. BOB NOBLE WAIVED WITNESS TO TEST. CONTINUE TO RU INNER REEL HARDLINE. RD TEST JOINT. 06:00 - 06:30 0.50 BOPSUF P PRE C/0 WITH DAY CREW. PERFORM WALK AROUNDS & SPILL CHAMPION. 06:30 - 08:30 2.00 BOPSUF P PRE INSTALL PACKOFF ASSEMBLY ON INJECTOR. PREP TO PULL COIL ACROSS. PULL AND STAB COIL. CONTINUE AND COMPLETE BOP TEST. BOP TEST AS PER AOGCC REGS, BP DWOP POLICY, PERMIT TO DRILL, AND APPROVED BP ADW WELL PLAN. ALL DATA RECOREDED ON PAPER, NORDIC AND SLB DIGITAL SYSTEM. DATA COMPILED AND REPORTED TO AOGCC REPRESENTATIVE VIA E -MAIL. 08:30 - 11:30 3.00 RIGU P PRE PULL COIL ACROSS. STAB IN TO INJECTOR. 11:30 - 15:30 4.00 BOPSUF N SFAL PRE PRESSURE TEST INNER REEL VALVE AND PACKOFF ASSEMBLY. LEAKS AT BULK HEAD. REBUILD SAME. GET TEST AT 250 AHD 3500 PSI. RECORD DATA. Printed: 12/21/2009 10:18:49 AM • BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: W -25 Common Well Name: W -25 Spud Date: 10/10/1988 Event Name: REENTER +COMPLETE Start: 11/18/2009 End: 12/10/2009 12/10/2009 Contractor Name: NORDIC CALISTA Rig Release: C g Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 11/28/2009 15:30 - 17:00 1.50 DRILL P WEXIT PUMP SLACK BACK IN TO REEL. TRIM COIL. 17:00 - 19:45 2.75 DRILL P WEXIT INSTALL CTC. REHEAD BHI. PRESSURE TEST & PULL TEST CTC - OK. 19:45 - 20:00 0.25 STWHIP P WEXIT PJSM REGARDING MU MILLING BHA. 20:00 - 20:45 0.75 STWHIP P WEXIT MU PILOT MILLING BHA. STAB ONTO WELL. 20:45 - 21:30 0.75 STWHIP P WEXIT TEST TOOLS - FAILED. TRBL SHOOT. SLOWLY RIH & CIRC MIN RATE TO PREVENT FREEZE UP. TAKE RETURNS OUTSIDE. PUH TO SURFACE. BRING RETURNS INSIDE. BLOW DOWN TT LINE. FLOW CHECK. POP OFF. 21:30 - 22:00 0.50 STWHIP N SFAL WEXIT TROUBLESHOOT E -LINE FROM RF END & REEL HOUSE END - BAD. CUT 15' & TEST - BAD. 22:00 - 22:25 0.42 STWHIP N SFAL WEXIT PJSM REGARDING CUTTING COIL. 22:25 - 00:00 1.58 STWHIP N SFAL WEXIT RU COIL CUTTER. CUT 100'. TEST WIRE - BAD. FILL PIT WITH RIG WATER. ORDER METHANOL. ORDER SPARE REEL. ORDER N2 UNIT. 11/29/2009 00:00 - 04:30 4.50 STWHIP N SFAL WEXIT CONTINUE TO SWAP REEL TO FRESH WATER. CONTINUE TO WAIT ON N2 UNIT & SPARE REEL (HAVE TO LOAD ONTO TRAILER IN SLB'S YARD). BLOW DOWN BHA & LAY IT DOWN. CLOSE MASTER & SWAB. TROUBLE SHOOT WITH SLB E -LINE TECHS. RD COIL CUTTER. E -LINE IS BROKEN IN THE MIDDLE OF THE REEL. 04:30 - 04:45 0.25 STWHIP N SFAL WEXIT PJSM REGARDING PUMPING NITROGEN. 04:45 - 05:20 0.58 STWHIP N SFAL WEXIT SPOT & RU NITROGEN UNIT. COOL DOWN & PRESSURE TEST SAME TO 3500PSI. STAB INJECTOR ONTO WELL. 05:20 - 05:40 0.33 STWHIP N SFAL WEXIT CIRCULATE 15BBLS OF INHIBITED WATER FOLLOWED BY 5BBLS OF METHANOL INTO THE REEL. ISOLATE RIG PUMPS. 05:40 - 06:00 0.33 STWHIP N SFAL WEXIT BLOW DOWN REEL WITH NITROGEN & TAKE RETURNS TO THE TIGER TANK. LET PRESSURE BLEED DOWN. 06:00 - 06:30 0.50 STWHIP N SFAL WEXIT CREW CHANGE. MAKE RIG ROUNDS. HOLD PJSM TO DICUSS REEL SWAP. 06:30 - 10:30 4.00 STWHIP N SFAL WEXIT RU TO UNSTAB COIL. SPOOL AND SECURE COIL ON TO REEL. REMOVE BULHEAD AND HADR LINE COMPONENTS IN THE REEL. HOLD PSJM WITH CREW AND CHILL DRIVERS. LOWER REEL FORM RIG AND SECURE ON TRAILER. 10:30 - 12:00 1.50 STWHIP N SFAL WEXIT SPOT REPLACEMENT REEL. LIFT IN TO POSITION AND MOUNT IN REEL HOUSE. 12:00 - 15:00 3.00 STWHIP N SFAL WEXIT HOLD PJSM. DRESS COIL AND INSTALL GRAPPLE. REMOVE SHIPPING BAR AND PULL COIL ACROSS TO INJECTOR. 15:00 - 21:00 6.00 STWHIP N SFAL WEXIT RU TO REVERSE SLACK TOWARDS REEL. 3850 PSI AT 2.52 BPM. HEAR WIRE MOVING IN REEL. RD REVERSE PUMPING EQUIPMENT. RU INNER REEL HARDLINE & BULKHEAD. 21:00 - 21:15 0.25 BOPSUF N SFAL WEXIT PJSM REGARDING PRESSURE TESTING INNER REEL & PACKOFFS. 21:15 - 22:00 0.75 BOPSUF N SFAL WEXIT PUMP 1OBBLS OF RIG WATER TO FILL & WARM UP COIL. PRESSURE TEST INNER REEL VALVE & PACKOOFS PER AOGCC REGS 250PSI /3500PSI - PASS. BLEED OFF. BLOW BACK CT WITH RIG AIR - 3BBLS RECOVERED. 22:00 - 22:15 0.25 STWHIP N SFAL WEXIT PJSM REGARDING CUTTING COIL. Printed: 12/21/2009 10:18:49 AM • BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: W -25 Common Well Name: W -25 Spud Date: 10/10/1988 Event Name: REENTER +COMPLETE Start: 11/18/2009 End: 12/10/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/10/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 11/29/2009 22:15 - 23:15 1.00 STWHIP N SFAL WEXIT CUT COIL TO FIND WIRE, 310'. TEST WIRE - GOOD. RD COIL CUTTER. 23:15 - 23:45 0.50 STWHIP N SFAL WEXIT MU SLB KENDAL CTC. PULL TEST TO 36K - GOOD. 23:45 - 00:00 0.25 STWHIP N SFAL WEXIT HEAD UP BHI. 11/30/2009 00:00 - 00:15 0.25 STWHIP N SFAL WEXIT CONTINUE TO HEAD BHI. TEST WIRE/UQC - GOOD. 00:15 - 00:30 0.25 STWHIP N SFAL WEXIT PRESSURE TEST CTC & UQC TO 4300PSI - PASS. PLACE INJECTOR OVER BUNG HOLE. CIRCULATE 1.5 TIMES COIL VOLUME FORWARD. 00:30 - 01:00 0.50 STWHIP N SFAL WEXIT PJSM REGARDING MU PILOT MILLING BHA. 01:00 - 01:20 0.33 STWHIP P WEXIT INSTALL NIGHT CAP. OPEN MASTER & SWAB. MU PILOT HOLE MILLING BHA. SET DOWN AT 30'. LD PILOT MILLING BHA. MU NOZZLE BHA. 01:20 - 01:45 0.42 STWHIP P WEXIT RIH HOLDING 200PSI WHP. JET ICE PLUG. DRIFT TO 200'. TAG UP. FLOW CHECK. 01:45 - 02:00 0.25 STWHIP P WEXIT LD NOZZLE BHA. MU PILOT HOLE MILLING BHA, MILL WAS 2.75" GO. STAB ONTO WELL. POWER UP & TEST TOOLS. SET COUNTERS. 02:00 - 04:25 2.42 STWHIP P WEXIT RIH. CIRC MIN RATE 0.25BPM/600PSI. TAKE RETURNS TO TIGER TANK. SWAP REEL & WELL TO USED GEOVIS. 04:25 - 05:05 0.67 STWHIP P WEXIT LOG DOWN FROM 9730' ( -26' & SUBTRACT 3' TO CORRECT TO PDC LOG). 05:05 - 05:10 0.08 STWHIP P WEXIT RIH & DRY TAG AT 9851'. 05:10 - 06:00 0.83 STWHIP P WEXIT MILL CEMENT PILOT HOLE FROM 9851' USING USED GEOVIS 1.5/1.5/2850/208 W/ 100 -200 PSI DIFF, 0.85 -1.5K WOB W/ 10.67 ECD MILL GOOD CEMENT FROM 9856'. ROP 20'- 35' /HR STALL AT 9870'. ROP 10'- 15' /HR FROM 9870' 06:00 - 06:30 0.50 STWHIP P WEXIT CREW CHANGE. DISCUSS OPS WITH RELIEF. MAKE RIG ROUNDS. PERFORM PJSMS AS REQUIRED. 06:30 - 12:00 5.50 STWHIP P WEXIT CONTINUE TO DRILL 2.74" PILOT HOLE FROM 9880'. 2950 PSI FS AT 1.53 BPM IN /OUT. 100 -200 PSI MTR WORK. 1.0 K# DHWOB. 20R TF. DRILL TO 9980'. 12:00 - 18:00 6.00 STWHIP P WEXIT CONTINUE TO DRILL PILOT HOLE FROM 9980'. 3050 PSI FS AT 1.56 BPM IN /OUT. 200 -300 PSI MTR WORK. 2.15K# DHWOB. 20 -25 fph ROP. DRILL TO 10085'. 18:00 - 18:30 0.50 STWHIP P WEXIT CREW CHANGE. MAKE HANDOVER. MAKE RIG ROUNDS. 18:30 - 22:55 4.42 STWHIP P WEXIT CONTINUE TO DRILL PILOT HOLE FROM 10085'. 3050 PSI FS AT 1.56 BPM IN /OUT. 200 -300 PSI MTR WORK. 1.5 -2.5K# DHWOB. 15 -25 FPH ROP. DRILL TO 10165'. 22:55 - 23:20 0.42 STWHIP P WEXIT SLOWLY PUH TO 9850'. 23:20 - 23:25 0.08 STWHIP P WEXIT RIH TO 9890', PUMP MIN RATE. 23:25 - 23:50 0.42 STWHIP P WEXIT BACKREAM 160L FROM 9890' TO 9850' AT 1' /MIN USING 1.5BPM. 23:50 - 23:55 0.08 STWHIP P WEXIT RIH TO 9895', PUMP MIN RATE. 23:55 - 00:00 0.08 STWHIP P WEXIT BACKREAM 160L FROM 9895' AT 1' /MIN USING 1.5BPM. Printed: 12/21/2009 10:18:49 AM • 1 110 BP EXPLORATION Page 4 of 13 Operations Summary Report Legal Well Name: W -25 Common Well Name: W -25 Spud Date: 10/10/1988 Event Name: REENTER +COMPLETE Start: 11/18/2009 End: 12/10/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/10/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/1/2009 00:00 - 00:25 0.42 DRILL P WEXIT CONTINUE TO BACKREAM 160L FROM 9895' TO 9860' AT 1' /MIN USING 1.5BPM. 00:25 - 00:40 0.25 DRILL P WEXIT RIH TO 10120', PUMP MIN RATE. 00:40 - 00:45 0.08 DRILL P WEXIT LOG DOWN FOR TIE -IN FROM 10120' (ZERO COORECTION). 00:45 - 00:50 0.08 STWHIP P WEXIT RIH & TAG AT 10165'. 00:50 - 02:45 1.92 STWHIP P WEXIT OPEN EDC. POH. PJSM WHILE POH REGARDING LD MILLING BHA. 02:45 - 03:10 0.42 STWHIP P WEXIT FLOW CHECK. POP OFF. STAND BACK INJECTOR. BLOW DOWN BHA WITH WATER & AIR. LD MOTOR & MILL. MILL WAS 2.74" GO, 2.73" NO -GO. 03:10 - 03:35 0.42 STWHIP P WEXIT MU DRIFT BHA. STAB ONTO WELL. POWER UP & TEST TOOLS. SET COUNTERS. 03:35 - 05:45 2.17 STWHIP P WEXIT RIH WITH DRIFT BHA. CIRC 1 BPM /1640PSI. RIH THROUGH PILOT HOLE SECTION AT 20' /MIN. TAG AT 10085'. PUH. TAG AT 10086.5' WITH 0.75BPM. PUH. TAG AT 10085' WITH NO PUMPS. 05:45 - 05:55 0.17 STWHIP P WEXIT PUH, CIRC 1.25BPM 05:55 - 06:20 0.42 STWHIP P WEXIT LOG DOWN FOR TIE -IN FROM 9780'. UNABLE TO TIE IN CORRECTLY. MUST BE WAY OFF DEPTH FOR SOME REASON. 06:20 - 07:30 1.17 STWHIP P WEXIT PUH TO 9700'. LOG CCL TIE IN. APPEAR TO BE 100' SHALLOW. MAKE CORRECTION. LOG GR TIE IN TO VERIFY DEPTH. ADD 79' CORRECTION. APPARENTLY BOTH SLB COUNTERS WERE OFF. PLAN TO CHECK BOTH WHEN AT SURFACE. TAG TD OF PILOT HOLE AT 10165'. 07:30 - 10:15 2.75 STWHIP P WEXIT CIRCULATE OUT OF HOLE. HOLD PJSM TO DISCUSS GETTING OFF WELL. ALSO DISCUSS INSTALLING PIP TAGS IN WHIPSTOCK. 10:15 - 10:45 0.50 STWHIP P WEXIT GET OFF WELL. UNSTAB COIL. LD 2.625" DRIFT ASSEMBLY. 10:45 - 11:45 1.00 STWHIP P WEXIT MU BTT GEN 2 3.5 X 4.5" WHIPSTOCK ON INTEQ BHA. CHANGE OUT INJECTOR DEPTH ENCODER ASSEMBLY. ORIENT WS TRAY FACE TO HS TOOL FACE. 11:45 - 15:15 3.50 STWHIP P WEXIT STAB COIL. GET ON WELL. RUN IN HOLE. 60 FPM MAX. 15:15 - 16:00 0.75 STWHIP P WEXIT LOG GR TIE IN FROM 9750'. SUBTRACT 4' CORRECTION TO PDC LOG. 32K# UP, 14K# DN WT AT 0.0 BPM. 16:00 - 16:45 0.75 STWHIP P WEXIT RUN IN HOLE. SET DOWN AT 9874'. PU AND RUN A LITTLE FASTER (20 FPM). POPPED THROUGH. SET WS TOP AT 10,100'. TRAY FACE IS HS. PRESSURE COIL TO SET ANCHOR. SET SHEARED AT 3650 PSI. 28K# UP WT AT 0.45 BPM. 16:45 - 19:00 2.25 STWHIP P WEXIT PULL OUT OF HOLE. PJSM TO LD WS SETTING BHA & PU WINDOW MILLING BHA WHILE POH 19:00 - 19:15 0.25 STWHIP P WEXIT STAND BACK INJECTOR & LD WS SETTING BHA 19:15 - 19:30 0.25 STWHIP P WEXIT PU WINDOW MILLING BHA ( .6 DEG MTR ) Printed: 12/21/2009 10:18:49 AM • BP EXPLORATION Page 5 of 13 Operations Summary Report p Y P Legal Well Name: W -25 Common Well Name: W -25 Spud Date: 10/10/1988 Event Name: REENTER +COMPLETE Start: 11/18/2009 End: 12/10/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/10/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/1/2009 19:15 - 19:30 0.25 STWHIP P WEXIT STAB INJECTOR 19:30 - 21:30 2.00 STWHIP P WEXIT RIH WITH WINDOW MILLING BHA TO 9,930' 21:30 - 22:30 1.00 STWHIP P WEXIT LOG TIE IN FROM 9,930' TO 9,958' STACKING 8K OF WT PU TO 9,920' LOG TIE IN FROM 9,920' TO 9,958' STACKING 4K OF WT PU TO 9,750' LOG TIE IN FROM 9,750' TO 9,770' CORRECTION OF -5' RESET DEPTH TO 9,766.4' 22:30 - 23:30 1.00 STWHIP P WEXIT RIH TO 9,958' STACKED 3.6K OF WT PU TO 9,920' BRING ON PUMPS TO 1.55BPM FS CP 3,075PSI RIH TIGHT SPOT CO 9,958', 10,038',10,075' RIH TROUGH TIGHT SPOTS @ 1.5FPM WITH LITTLE OR NO MOTOR WORK RIH TO TOWS @ 10,099.9' 23:30 - 00:00 0.50 STWHIP P WEXIT MILL WIDOW FROM 10,099.9' 1.5BPM, FS 3,050PSI TIME MILL WINDOW @ 1 FPH 100 - 160PSI & 0.1 - 0.8K WOB 12/2/2009 00:00 - 05:00 5.00 STWHIP P WEXIT MILL WINDOW 1.5BPM, FS 3,050 10,000.7' @ 00:30 100- 150PSI, .8- 1.2KWOB 10,001.3' CO 01:20 100 - 150PSI, 1 - 1.2K WOB 10,102.3' CO 02:15 110 - 200PSI, 1.2 - 1.7K WOB 10,103.5 CO 03:30 110 - 150PSI, 1.2 - 1.7K WOB 10,104.2 @ 04:30 100 - 140PSI, .4 - .6K WOB 10,105.4' 10 - 50PSA, .1 - .5K WOB 05:00 - 06:00 1.00 STWHIP P WEXIT CONTINUE TO MILL 2.74" WINDOW. 3025 PSI FS AT 1.54 BPM IN /OUT. <100 PSI MTR WORK. 06:00 - 06:30 0.50 STWHIP P WEXIT CREW CHANGE. DISCUSS OPS. MAKE RIG ROUNDS. CONTINUE TO MILL WINDOW. PROBABLY INTO FORMATION. MINOR MTR WORK AND 0.33K# DHWOB.. 06:30 - 08:00 1.50 STWHIP P WEXIT MILL/DRILL AHEAD FROM 10,106'. BHP /ECD: 4737 PSI / 10.55 PPG. PVT: 335 BBLS. IA/OA: 175 PSI / 287 PSI. BTMS UP SAMPLE SHOWS 50% FORMATION (SHUBLIK) CONTINUE TO DRILL RAT HOLE. TD rat hole at 10,114'. 08:00 - 09:15 1.25 STWHIP P WEXIT DRESS WINDOW BY MAKING THREE UP REAM PASSES. DRY DRIFT WINDOW. LOOKS SMOOTH. 09:15 - 11:45 2.50 STWHIP P WEXIT PULL ABOVE PILOT HOLE. OPEN EDC. CIRCULATE OUT OF HOLE. 3050 PSI AT 1.96 BPM IN. Printed: 12/21/2009 10:18:49 AM BP EXPLORATION Page 6 of 13 Operations Summary Report Legal Well Name: W -25 Common Well Name: W -25 Spud Date: 10/10/1988 Event Name: REENTER +COMPLETE Start: 11/18/2009 End: 12/10/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/10/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase _. Description of Operations 12/2/2009 11:45 - 12:45 1.00 STWHIP P WEXIT AT SURFACE. GET OFF WELL. UNSTAB COIL.LD MILLING BHA. MILL GAUGED 2.74 ", SAME AS NEW. 12:45 - 13:45 1.00 DRILL N SFAL PROD1 HOLD PJSM WITH SLB N2 CREW. RU N2 PUMPERS. 13:45 - 17:30 3.75 DRILL N SFAL PROD1 FLUSH REEL WITH FRESH WATER, MEOH,. BLOW DOWN WITH N2. 15:00 - 18:00 3.00 DRILL N SFAL PROD1 HOLD PJSM. RESTRICT ACCESS TO REEL HOUSE AREA OF RIG. INSTALL GRAPPLE. UNSTAB COIL FROM INJECTOR. PULL COIL. SECURE ON REEL. 18:00 - 18:15 0.25 DRILL N SFAL PROD1 PJSM TO LOWER REEL & SECURE TO TRAILER 18:15 - 18:45 0.50 DRILL N SFAL PROD1 LOWER REEL & SECURE TO TRAILER SWAP TRAILERS POSITION NEW REEL UNDER REELHOUSE 18:45 - 19:00 0.25 DRILL N SFAL PROD1 PJSM TO PU NEW REEL & SECURE IN REEL HOUSE 19:00 - 19:45 0.75 DRILL N SFAL PROD1 PU NEW REEL & SECURE IN REEL HOUSE 19:35 - 19:45 0.17 DRILL N SFAL PROD1 PJSM TO MU HARDLINE IN REEL HOUSE 19:45 - 22:55 3.17 DRILL N SFAL PROD1 MU HARDLINE IN REEL HOUSE MU & TEST E -LINE 22:55 - 23:10 0.25 DRILL N SFAL PROD1 PJSM TO PULL COIL ACROSS TO INJECTOR 23:10 - 00:00 0.83 DRILL N SFAL PROD1 PULL COIL ACROSS TO INJECTOR 12/3/2009 00:00 - 00:50 0.83 DRILL N SFAL PROD1 PULL COIL ACROSS TO INJECTOR 00:50 - 02:30 1.67 DRILL N SFAL PROD1 CONDUCT SLACK MANAGEMENT FOR NEW COIL 02:30 - 03:30 1.00 DRILL N SFAL PROD1 PT INNER REEL VALVE 03:30 - 03:45 0.25 DRILL N SFAL PROD1 PJSM TO RU & CUT COIL 03:45 - 04:00 0.25 DRILL N SFAL PROD1 RU & CUT 4.9' OF COIL 04:00 - 04:10 0.17 DRILL N SFAL PROD1 PJSM TO INSTALL CTC & HEAD UP COIL 04:10 - 06:00 1.83 DRILL N SFAL PROD1 INSTALL CTC, HEAD UP COIL & PULL TEST SAME 06:00 - 06:15 0.25 DRILL N SFAL PROD1 CREW CHANGE. DISCUSS OPERATIONS. MAKE RIG ROUNDS. 06:15 - 07:30 1.25 DRILL P PROD1 MU DRILLING BHA. 1.5 DEG MTR WITH HTC REBUILD BICENTER. 07:30 - 09:15 1.75 DRILL P PROD1 STAB COIL. TEST TOOLS. GET ON WELL. RUN IN HOLE. 09:15 - 09:30 0.25 DRILL P PROD1 LOG GR TIE IN FROM 9750'. SUBTRACT 10' CORRECTION. 09:30 - 09:45 0.25 DRILL P PROD1 RUN IN HOLE. CLOSE EDC. RUN THROUGH WINDOW TAG TD AT 10114'. 09:45 - 10:15 0.50 DRILL P PROD1 DRILL AHEAD FROM 10114'. 3010 PSI FS AT 1.56 BPM IN /OUT. 150 -250 PSI MTR WORK. 1.5 -2.0K# DHWOB. IA/OA: 16 PSI / 144 PSI. PVT: 288 BBLS. DRILL TO 10122'. 10:15 - 10:45 0.50 DRILL P PROD1 GAS IN RETURNS. PULL INTO CASING. CIRCULATE TO TIGER TANK. WHP: 110 PSI FOR A FEW MINUTES. 10:45 - 14:30 3.75 DRILL P PROD1 DRILL AHEAD FROM 10,122. 2900 PSI FS AT 1.53 BPM IN /OUT. 200 -300 PSI MTR WORK. 0.5 K# DHWOB. 15 -20 FPH ROP. STALLS IF PUSHED. DRILL TO 10,171'. 14:30 - 16:00 1.50 DRILL P PROD1 DRILL AHEAD FROM 10,171'. 3050 PSI FS AT 1.53 BPM IN /OUT. 1.52K# DHWOB. Printed: 12/21/2009 10:18:49 AM • • BP EXPLORATION Page 7 of 13 Operations Summary Report Legal Well Name: W -25 Common Well Name: W -25 Spud Date: 10/10/1988 Event Name: REENTER +COMPLETE Start: 11/18/2009 End: 12/10/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/10/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/3/2009 14:30 - 16:00 1.50 DRILL P PROD1 DRILL TO 10,200'. RA MARKER IS MASKED BY GR SPIKE IN SHUBLIK. OFFICIAL WINDOW TOP : 10,100', BOW: 10,105', RA TAG: 10,105'. 16:00 - 18:50 2.83 DRILL P PROD1 DRILL AHEAD FROM 10,200'. 2990 PSI FS AT 1.53 BPM IN /OUT. 2.03K# WOB DRILL TO 10,250' 18:50 - 19:40 0.83 DRILL P PROD1 WIPER TO 10,120' 19:40 - 00:00 4.33 DRILL P PROD1 DRILL AHEAD FROM 10,250'. 3475 PSI FS AT 1.52 BPM IN /OUT. 1.5K TO 2.03K# WOB 100 TO 150PSI DRILL TO 10,327' 12/4/2009 00:00 - 03:00 3.00 DRILL P PROD1 DRILL AHEAD FROM 10,327'. 3200 PSI FS AT 1.48 BPM IN /OUT. 1K TO 2K# WOB 100 TO 150PSI DRILL TO 10,400' 03:00 - 03:35 0.58 DRILL P PROD1 WIPER TRIP TO 10,120' 03:35 - 05:00 1.42 DRILL P PROD1 DRILL AHEAD FROM 10,400'. 3450 PSI FS AT 1.52 BPM IN /OUT. 1K TO 2K# WOB 200 TO 450PSI DRILL TO 10,440' 05:00 - 06:00 1.00 DRILL P PROD1 DRILL AHEAD FROM 10,440'. 3450 PSI FS AT 1.52 BPM IN /OUT. 1K TO 2K# WOB 200 TO 450PSI. DRILL TO 10,470'. 06:00 - 06:15 0.25 DRILL P PROD1 CREW CHANGE. DISCUSS OPS. MAKE RIG ROUNDS. 06:15 - 09:30 3.25 DRILL P PROD1 DRILL AHEAD FROM 10,470'. 3380 PSI FS AT 1.49 BPM IN /OUT. 100 -200 PSI MTR WORK. 0.2K# DHWOB. ROP: 40 -50 FPH. IA/OA: 392 PSI / 195 PSI. PVT: 413 BBLS. DRILL TO 10550'. 09:30 - 10:00 0.50 DRILL P PROD1 WIPER TRIP TO WINDOW. LOG TIE IN. HOLE SMOOTH. ADD 1.5' CORRECTION. 10:00 - 13:30 3.50 DRILL P PROD1 DRILL AHEAD FROM 10,550'. 3400 PSI FS AT 1.54 BPM IN /OUT. 200 -250 PSI MT WORK 1 -2.5 K# DHWOB ROP: 40 -60 FPH. DRILL TO 10,700'. 13:30 - 14:30 1.00 DRILL P PROD1 MAKE WIPER TRIP TO WINDOW. HOLE SMOOTH. 14:30 - 17:30 3.00 DRILL P PROD1 DRILL AHEAD FROM 10,700'. 3450 PSI FS AT 1.54 BPM IN /OUT. 1 -2K# DHWOB ROP: 50 -60 FPH DRILL TO 10,850' 17:30 - 19:00 1.50 DRILL P PROD1 WIPER TRIP TO WINDOW. HOLE SMOOTH. 19:00 - 21:00 2.00 DRILL P PROD1 DRILL AHEAD FROM 10,850'. 3450 PSI FS AT 1.54 BPM IN /OUT. 1 -3K# DHWOB ROP: 50 -60 FPH DRILL TO 10,982' 21:00 - 22:50 1.83 DRILL P PROD1 WIPER TO WINDOW LOG TIE IN +2' CORRECTION Printed: 12/21/2009 10:18:49 AM • • BP EXPLORATION Page 8 of 13 Operat Summary Report Legal Well Name: W -25 Common Well Name: W -25 Spud Date: 10/10/1988 Event Name: REENTER +COMPLETE Start: 11/18/2009 End: 12/10/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/10/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/4/2009 21:00 - 22:50 1.83 DRILL P PROD1 HOLE SMOOTH 22:50 - 00:00 1.17 DRILL P PROD1 DRILL AHEAD FROM 10,982'. 3600 PSI FS AT 1.54 BPM IN /OUT. 1 -3K# DHWOB ROP: 50 -60 FPH DRILL TO 11,110' 12/5/2009 00:00 - 01:15 1.25 DRILL P PROD1 DRILL AHEAD FROM 11,110'. 3600 PSI FS AT 1.54 BPM IN /OUT. 1 -3K# DHWOB ROP: 3 -5 FPH DRILL TO 11,115' 01:15 - 02:05 0.83 DRILL P PROD1 WIPER TRIP TO WINDOW HOLE SMOOTH 02:05 - 05:00 2.92 DRILL P PROD1 DRILL AHEAD FROM 11,110'. 3600 PSI FS AT 1.54 BPM IN /OUT. 1 -3K# DHWOB ROP: 3 -80 FPH DRILL TO 11,210' 05:00 - 05:15 0.25 DRILL P PROD1 DRILL AHEAD FROM 11,210'. 3600 PSI FS AT 1.54 BPM IN /OUT. 1 -3K# DHWOB ROP: 10- 100FPH _peal TO 11,240' CALLED TO 05:15 - 06:00 0.75 DRILL P PROD1 WIPER TO WINDOW 3650 PSI FS AT 1.57 BPM IN. 06:00 - 06:15 0.25 DRILL P PROD1 CREW CHANGE. DISCUSS OPERATIONS. MAKE RIG ROUNDS. 06:15 - 06:45 0.50 DRILL P PROD1 LOG GR TIE IN. ADD 2' CORRECTION. 06:45 - 07:45 1.00 DRILL P PROD1 CONTINUE WIPER TRIP. 3665 PSI FS AT 1.58 BPM IN. PVT: 324 BBLS. SHALE AT 11005' A LITTLE TIGHT. CLEAN OUT SAME. TAG TD AT 11,240' CORRECTED. 07:45 - 09:15 1.50 DRILL P PROD1 MAKE 2ND WIPER TO WINDOW. RIH. 09:15 - 12:30 3.25 DRILL P PROD1 PLIQH AND LAY IN HL:V,IS.PILI. AT S REAG.E 12:30 - 13:30 1.00 DRILL P PROD1 GET OFF WELL. UNSTAB COIL CIRCULATE OVER BUNG HOLE. LD INTEQ TOOLS. 13:30 - 15:30 2.00 CASE P RUNPRD PUMP SLACK FORWARD OVER BUNG HOLE. RECOVER AND CUT 295' of wire. CALCULATED EXCESS WIRE IS 318' CIRCULATE 3/4" BALL RU FLOOR TO RUN LINER. 15:30 - 15:45 0.25 CASE P RUNPRD HOLD PJSM TO DISCUSS RUNNING LINER. 15:45 - 18:00 2.25 CASE P RUNPRD MU 52 Q.. JTS F 2 -3/8 LINER. TORQUE IS 500 -700. DRIFT EACH WITH 1.7" OD DRIFT FILL EVERY 10 JTS. 18:00 - 18:30 0.50 CASE P RUNPRD CREW CHANGE OUT PJSM TO DISCUSS RUNNING LINER 18:30 - 20:45 2.25 CASE P RUNPRD CONTINUE TO MU 52 JTS OF 2 -3/8" LINER. TORQUE IS 500 -700. DRIFT EACH WITH 1.7" OD DRIFT FILL EVERY 10 JTS. 20:45 - 21:00 0.25 CASE P RUNPRD PJSM TO RIG UP FALSE FLOOR FOR RUNNING 1" CSH 21:00 - 21:40 0.67 CASE P RUNPRD RIG UP FALSE FLOOR FOR RUNNING 1" CSH 21:40 - 21:50 0.17 CASE P RUNPRD PJSM TO RUN 50 JTS OF 1" CSH INNER STRING Printed: 12/21 /2009 10:18:49 AM • • BP EXPLORATION Page 9 of 13 Operations Summary Report Legal Well Name: W -25 Common Well Name: W -25 Spud Date: 10/10/1988 Event Name: REENTER +COMPLETE Start: 11/18/2009 End: 12/10/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/10/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/5/2009 21:50 - 00:00 2.17 CASE P RUNPRD 1314N 59 JTS OF_1 "CSH INNER STRING RAN CSH TO SPECIFIED DEPTH AS PLANNED SET DOWN TWICE @ CALCULATED DEPTH OF SHEAR PIN PU AGAIN & SET DOWN APPROXIMATLY 20' TO HIGH DID CALCULATIONS MATH ON TALLIES WAS CORRECT STNGER WAS NOT CALCULATED IN TALLY 12/6/2009 00:00 - 00:25 0.42 CASE N HMAN RUNPRD PJSM TO PULL 1" CSH & STAND BACK IN DERRICK 00:25 - 04:30 4.08 CASE N HMAN RUNPRD PULL 1" CSH & STAND BACK IN DERRICK 01:45 - 02:00 0.25 CASE N HMAN RUNPRD PJSM TO RIG DOWN FALSE FLOOR FROM CSH RUN 02:00 - 02:30 0.50 CASE N HMAN RUNPRD RD FALSE FLOOR FROM CSH RUN 02:30 - 02:45 0.25 CASE N HMAN RUNPRD PJSM TO STAND BACK 2 -3/8" STL IN DERRICK 02:45 - 04:30 1.75 CASE N HMAN RUNPRD STAND BACK 2 -3/8" STL IN DERRICK 04:30 - 05:00 0.50 CASE N HMAN RUNPRD INSPECT 0-RING SUB & RE -PIN FLAPPER VALVE 05:00 - 05:15 0.25 CASE N HMAN RUNPRD PJSM TO MU 2 -3/8" STL LINER ASSY 05:15 - 06:00 0.75 CASE N HMAN RUNPRD MU 2 -3/8" STL LINER ASSY 06:00 - 06:15 0.25 CASE N HMAN RUNPRD CREW CHANGE. DISCUSS OPERATIONS. MAKE RIG CHECKS AND ROUNDS. HOLD PJSM WITH RELIEF BTT HAND. 06:15 - 06:45 0.50 CASE N HMAN RUNPRD MU DRIFT ASSEMBLY WITH CSH PUP JOINT. 06:45 - 09:00 2.25 CASE N HMAN RUNPRD CONTINUE TO RUN LINER IN DOUBLES FROM DERRICK. FILL LINER EVERY 5 STANDS. 09:00 - 11:30 2.50 CASE N HMAN RUNPRD MU STINGER. RUN 1" CSH FROM DERRICK. SPACE OUT SAME. DID NOT SEE FLOAT SUB SHEAR PIN. 11:30 - 13:00 1.50 CASE P RUNPRD TEST CSH X LINER ANN. MU LINER RUNNING TOOL AND 6 JTS 2- 1/16" PH -6. STAB COIL. GET ON WELL. 13:00 - 14:45 1.75 CASE P RUNPRD RUN IN HOLE WITH LINER. CIRCULATE AT MIN RATE. 1560 PSI AT 0.21 BPM IN. PVT: 362 BBLS. 14:45 - 17:00 2.25 CASE P RUNPRD PU WT DRY AT 9840' : 36k #, 18k# do wt. RUN IN TO OPEN HOLE. 1820 PSI AT0.14 BPM IN. SET DOWN HARD AT 10993' AT 30 FPM. CANNOT PUMP MORE THAN MIN RATE WITHOUT RISK OF LOSING LINER. SET DOWN A TOTAL OF 4 TIMES VARYING RUNNING SPEED. POPPED THROUGH. CONTINUE TO RUN IN HOLE. SELnaV1 BABLIAL 11,.13 _PU CLEAN - 35K# REPEAT. 17:00 - 20:00 3.00 CASE P RUNPRD CIRCULATE MUD AT 2115 PSI AT 0.33 BPM IN /OUT. DISPLACE TO SLICK 2% KCL WATER. 20:00 - 20:15 0.25 CASE P RUNPRD PJSM TO DROP 5/8" STEEL BALL TO RELEASE FROM LINER 20:15 - 21:30 1.25 CASE P RUNPRD PUMP 5BBLS BIO FROM PITS DROP 5/8" STEEL BALL BALL LAUNCH WITH 5BBLS OF 2PPB BIOZAN @ 900PSI FOLLOWED BY KCL DID NOT HEAR BALL IN REEL PUMP 51 BBLS BALL NOT ON SEAT 21:30 - 21:40 0.17 CASE P RUNPRD PJSM TO BREAK OFF VALVE FROM HARLINE IN REEL TO Printed: 12/21/2009 10:18:49 AM • i BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: W -25 Common Well Name: W -25 Spud Date: 10/10/1988 Event Name: REENTER +COMPLETE Start: 11/18/2009 End: 12/10/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/10/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/6/2009 21:30 - 21:40 0.17 CASE P RUNPRD LOOK FOR BALL 21:40 - 22:00 0.33 CASE P RUNPRD LOOK FOR BALL IN HARDLINE NO BALL FOUND, LOAD • - • ► . .: LQDSE.FROM COIL 22:00 - 22:45 0.75 CASE P RUNPRD _LAUNCH PIG WITH 800PSI PUMP 35.7BBLS BALL ON SEAT PRESSURE UP & SHEAR PINS @ 4,300PSI PU LINER RUNNING WT WAS 36K BREAKOVER WT 28.5K ST DOWN WITH 10K & ESTABLISH CIRCULATION 22:45 - 23:00 0.25 CEMT P RUNPRD PJSM TO RU CEMENTERS 23:00 - 23:20 0.33 CEMT P RUNPRD RU CEMENTERS 23:20 - 23:35 0.25 CEMT P RUNPRD PJSM TO PT CEMENTERS LINES & PUMP CMT 23:35 - 00:00 0.42 CEMT P RUNPRD PUMP 5 BBLS KCL TO CEMENTERS TO CHARGE LINES PT CMT LINES TO 4,500PSI BATCH UP &PUMP CMT 12/7/2009 00:00 - 01:50 1.83 CEMT P RUNPRD PUMP CMT ZERO IN MM WHEN DENSITY REACHES L„4,5PP, „ H LQ,QAN C 4.ENTERq,..9 413. LS CMT IN COIL ISOLATE COIL FROM CEMENTERS CONTINUE CMT JOB W/ RIG PUMPS CHASING CMT W/ 2PPB BIOZAN 8BBLS - PUMP .8BPM @ 3,500PSI 24BBLS - CMT OVER GOOSE NECK - PUMP .9BPM (6 2,700 - 2,900PSI 39BBLS - OUT RATE DROPPED OFF TO .23 FROM .88BPM PUMP DROPPED TO 2,200PSI, IA PRESSURE CLIMBED TO 1,000 AT THE HIGHEST POINT 42BBLS - CMT AT SHOE ZERO OUT MM & PUMP 6BBLS CMT 48BBLS - UNSTING FROM LINER & EXHAUST 2BBLS CMT IN LINER 5OBBLS - PU REPLACING VOIDAGE W/ BIOZAN 01:50 - 02:20 0.50 CEMT P RUNPRD PU TO 9,695' REPLACING VOIDAGE W/ BIOZAN IN RATE .28BPM OUT .13BPM @ 875PSI IA 580PSI 02:20 - 05:15 2.92 CEMT P RUNPRD CIRCULATE BU @ 1.87BPM 3,600PSI RIH @ 6.5FPM RIH TO PBTD POOH CIRCULATING @ 1.9BPM 2,600PSI PJSM TO LD LINER RUNNIG ASSY WHILE POOH LINER TOP LATER FOUND AT 9624', AND PBTD AT 11,187' AS PER SLB GR/CCL OF 12/8/09. 05:15 - 05:55 0.67 CEMT P RUNPRD LD LINER RUNNING ASSY & STAND BACK CSH IN DERRICK. FIND PINHOLE IN 2- 1/16" PH -6. 05:55 - 06:15 0.33 CEMT P RUNPRD CREW CHANGE. DISCUSS OPERATIONS. MAKE RIG CHECKS AND ROUNDS. 06:15 - 09:00 2.75 CEMT P RUNPRD STAND BACK CSH IN DERRICK. 09:00 - 10:00 1.00 CEMT P RUNPRD MU SWIZZLE JOINT ON COIL. GET ON WELL AND JET SURFACE BOP EQUIPMENT. LD SAME. 10:00 - 13:00 3.00 EVAL P RUNPRD MU CLEAN OUT BHA. 1.875" DSM ON 1- 11/16" MTR, 50 JTS 1" CSH, 2 JTS PH -6. STAB COIL GET ON WELL. 13:00 - 16:00 3.00 EVAL P RUNPRD RUN IN HOLE. Printed: 12/21/2009 10:18:49 AM • • BP EXPLORATION Page 11 of 13 Operations Summary Report Legal Well Name: W -25 Common Well Name: W -25 Spud Date: 10/10/1988 Event Name: REENTER +COMPLETE Start: 11/18/2009 End: 12/10/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/10/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/7/2009 13:00 - 16:00 3.00 EVAL P RUNPRD CIRC AT 1450 PSI AT 0.75 BPM IN. IA PRESS: 450 PSI. SLOWLY INCREASING WITH DEPTH. MAXIMUM NOTED WAS 650 PSI. ZERO MM OUT AT LINER TOP 0 9640'. RIH AT 20 FPM. TAKE WEIGHT 10,555'. 28k# PU WT. 16K# DN WT. MILL CEMENT FROM 11,162' TO 11,171'. uNABLE TO MAKE ANY MORE PROGRESS. 16:00 - 18:50 2.83 EVAL P RUNPRD CIRCULATE OUT OF HOLE. 2065 PSI AT 0.95 BPM IN. TAGGED UP AT SURFACE. 18:50 - 19:05 0.25 EVAL P RUNPRD PJSM TO UNSTAB AND STAND BACK INJECTOR. 19:05 - 19:40 0.58 EVAL P RUNPRD UNSTAB AND STAND BACK INJECTOR. 19:40 - 20:00 0.33 EVAL P RUNPRD PJSM TO STANDBACK CSH AND LAY DOWN CLEANOUT ASSEMBLY. 20:00 - 21:45 1.75 EVAL P RUNPRD STANDBACK CSH. LAY DOWN CLEANOUT ASSEMBLY. NOTE: SLB LAB CALLS AT 20:54 WITH UCA RESULTS - CEMENT SAMPLE JUST REACHED 2000 PSI COMPRESSIVE STRENGTH. 21:45 - 22:10 0.42 EVAL P RUNPRD PJSM FOR MAKING UP LOGGING BHA. 22:10 - 22:18 0.13 EVAL P RUNPRD DISCUSS PLAN FORWARD WITH TOWN ENGINEER. DECIDE TO PERFORM LINER LAP TEST PRIOR TO LOGGING RUN. 22:18 - 22:38 0.33 EVAL P RUNPRD BEGIN TO PRESSURE UP WELLBORE FOR LINER LAP PRESSURE TEST. INITIAL PRESSURES - T/1/0: 60/500/194 PSI. UPON APPLYING PRESSURE TO THE WELLBORE, THE INNER ANNULUS PRESSURETRACKS WELLHEAD PRESSURE IMMEDIATELY AND LINEARLY (IAP REMAINS ROUGHLY 430 PSI GREATER THAN WELLBORE PRESSURE). 22:38 - 22:43 0.08 EVAL P RUNPRD DOWN ON PUMP, T /I /O PRESSURES: 1930/2360/214 PSI. PRESSURES SLOWLY FALLING ON BOTH THE TUBING AND INNER ANNULUS AT A RATE OF APPROXIMATELY 70 PSI IN 5 MINUTES. DISCOVER SMALL DRIPS COMING FROM THE BAKER CHOKE LINE (WHICH IS SINGLE ISOLATED). REPRESSURE SYSTEM AND DOUBLE ISOLATE BAKER CHOKE. 22:45 - 23:28 0.72 EVAL P RUNPRD RESTART TEST WITH BAKER CHOKE DOUBLE ISOLATED. INITIAL T/I/0 PRESSURES: 1915/2349/214 PSI. AFTER 10 MINUTES, PRESSURES HAVE FALLEN TO 1692/2125/211 PSI. VERIFY ANNULAR PRESSURE VALUES AT MECHANICAL GAUGES AT WELLHEAD. AFTER 20 MINUTES, PRESSURES HAVE FALLEN TO 1608/2039/210 PSI. AFTER 30 MINUTES, PRESSURES HAVE FALLEN TO 1549/1980/209 PSI. TOTAL LOSS IN 30 MINUTES IS -19 PERCENT, LINER LAP PRESSURE TEST FAILED. ZERO RETURN MM AND SLOWLY BLEED DOWN WHP. IAP FALLS LINEARLY WITH WHP, REMAINING -430 PSI GREATER THAN WHP. RETURNED A TOTAL OF 4.3 BBLS FLUID TO REDUCE WHP FROM 1549 PSI TO ZERO PSI. IAP STABILIZES AT 450 PSI. 23:28 - 23:59 0.52 P LOWER1 BEGIN MAKING UP CSH AND LOGGING ASSEMBLY. CONTINUED ON DIMS REPORT 12/08/09. Printed: 12/21 /2009 10:18:49 AM BP EXPLORATION Page 12 of 13' Operations Summary Report Legal Well Name: W -25 Common Well Name: W -25 Spud Date: 10/10/1988 Event Name: REENTER +COMPLETE Start: 11/18/2009 End: 12/10/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/10/2009 Rig Name: NORDIC 2 Rig Number: N2 Date, From - To Hours Task Code NPT Phase Description of Operations 12/8/2009 00:00 - 01:30 1.50 EVAL P LOWER1 CONTINUED FROM DIMS 12/07/09. CONTINUE MAKING UP CSH AND LOGGING BHA. 01:30 -03:10 1.67 EVAL P LOWER1 , GIN 3IH WITH SLB_.OR/CCL MEMORY LOGGING TOOLS ON BAKER BHA. TOTAL BHA LENGTH IS 1678.76. 03:10 - 04:30 1.33 EVAL P LOWER1 BEGIN LOG DOWN AT 60 FPM FROM 9000' CTMD TO TAG AT 11,174' CTMD. LOG UP AT 60 FPM FROM 11174' CTMD WHILE LAYING IN PERF PILL. PAINT FLAG AT 8882.1' CTMD. 04:30 - 05:55 1.42 EVAL P LOWER1 POOH WITH LOGGING BHA. 05:55 - 06:15 0.33 EVAL P LOWER1 PJSM FOR STANDING BACK CSH AND LAYING DOWN LOGGING BHA. 06:15 - 09:00 2.75 EVAL P LOWER1 STAND BACK CSH. DOWN LOAD AND PROCESS LOG DATA. RIG UP LINE FROM WELL HEAD IA VALVES TO FLOW BACK TANK. 09:00 - 11:00 2.00 EVAL P LOWER1 SLB GC /CCL LOG DATED 12/8/09 SHOWS LINER TOP AT 9624 ELM, AND PBTD AT 11,187'. CONTINUE TO RIG UP FLOW BACK LINE. 11:00 - 13:00 2.00 EVAL P LOWER1 EVALUATE TBG LEAK. WITH 60 PSI WHP, LEAK RATE WAS 11 BBLS IN 5 MINUTES. RD FLOW BACK LOOP. DISCUSS W/ TOWN. WILL LEAVE FUTURE DIAGNOSTICS FOR WELLS GROUP. WILL PERFORATE, THEN RDMO 13:00 - 15:50 2.83 PERFOB N WAIT LOWER1 WO SWS PERFORATORS LOAD GUNS IN PIPESHED 15:50 - 16:05 0.25 PERFOB P LOWER1 SAFETY MTG RE: MU PERF GUNS 16:05 - 18:00 1.92 PERFOB P LOWER1 MU 882' OF SWS 1.56" 1606 PJ GUNS LOADED AT 6 SPF 18:00 - 19:30 1.50 PERFOB P LOWER1 MU 29 JTS 1" CSH FROM DERRICK 19:30 - 22:15 2.75 PERFOB P LOWER1 RIH WITH PERFORATING ASSEMBLY. AT 21:47 HOURS, GET VERBAL CONFIRMATION FROM TOWN ENGINEER THAT THE REALTIME MWD LOG REQUIRED NO DEPTH SHIFTING AFTER INITIAL PRINTING AND IS ON DEPTH WITH THE PDC LOG, AND THAT THE PERFORATION PICKS WERE DEPTH REFERENCED TO THE REALTIME MWD LOG. 22:15 - 23:40 1.42 PERFOB P LOWER1 PARK AT WHITE FLAG. ELECTRONIC DEPTH READS 9057.7'. MECHANICAL COUNTER READS 7197'. CONTINUE RIH TO PERF DEPTH. UP WEIGHT ON BOTTOM IS 31,000 LB. TAG TD AT 11,188' CTMD (WITH COIL IN TENSION). MECHANICAL COUNTER READS 9328'. CORRECT DEPTH ON BOTTOM TO READ CORRECTED BOTTOM SHOT AT TAG OF 11,178.6' (WITH REFERENCE TO REALTIME BAKER INTEQ GR MWD LOG 05- DEC -09). PARK AT SHOOT DEPTH, WITH BOTTOM SHOT AT 11,175' MD. INITIATE FIRING SEQUENCE. FIRE GUNS ON THE FLY (CONFIRM SHOT WITH PORTABLE SEISMIC SHOT DETECTOR). NO OVERPULLS NOTED AFTER FIRING. PERFORATED FOLLOWING INTERVALS (DEPTHS REFERENCED TO REALTIME BAKER INTEQ GR/MPR MWD LOG DATED 05- DEC -09): 10325' - 10370', 10390' - 10400', 10540' - 10625', 10645' - 10905', 10930' - 10970', 10990' - 11070', 11095' - 11105', 11125' - 11145', 11160' - 11175'. L ` Printed: 12/21 /2009 10:18:49 AM r • . BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: W -25 Common Well Name: W -25 Spud Date: 10/10/1988 Event Name: REENTER +COMPLETE Start: 11/18/2009 End: 12/10/2009 Contractor Name: NORDIC CALISTA Rig Release: 12/10/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/8/2009 23:40 - 00:00 0.33 PERFOB P LOWER1 BEGIN POOH WITH PERFORATING ASSEMBLY. CONTINUED ON DIMS REPORT DATED 09- DEC -09. 12/9/2009 00:00 - 01:00 1.00 PERFOB P LOWER1 CONTINUED FROM DIMS REPORT 08- DEC -09. PULL TO SURFACE WITH PERFORATING ASSEMBLY. 01:00 - 01:30 0.50 PERFOB P LOWER1 SAFETY TABLE TOP DRILLS: KICK WHILE DRILLING, SPILL, FIRE. 01:30 - 01:45 0.25 PERFOB P LOWER1 PJSM FOR LAYING DOWN CSH. 01:45 - 03:45 2.00 PERFOB P LOWER1 LD CSH. 03:45 - 04:10 0.42 PERFOB P LOWER1 PJSM FOR LAYING DOWN PERF GUNS. 04:10 - 08:45 4.58 PERFOB P LOWER1 BEGIN TO LAY DOWN PERF GUNS. FIRING HEAD IS SHIFTED, INDICATING GOOD FIRE. GUNS ARE COMING OUT FULLY FIRED. FIN LD PERF GUNS, ASF. LOAD OUT GUNS 08:45 - 10:15 1.50 PERFOB P LOWER1 RIH W/ EXCESS CSH STANDS OUT OF DERRICK. POOH AND LD SINGLES 10:15 - 12:00 1.75 WHSUR P POST RU NOZZLE ASSY RIH W/ NOZZLE TO 2500'. POOH FP WELLBORE W/ 22 BBLS DIESEL` " "' 12:00 - 13:30 1.50 WHSUR P POST SAFETY IMITGS RU SWS N2 PUMPER DSM GREASE TREE VALVES DSM SET TWC (DSM REQUEST FOR WELLHEAD WORK). WELL ON SLI VAC. DRY ROD SET TWC 13:30 - 15:30 2.00 RIGD P POST RU NOZZLE ASSY AND STAB ON DISPLACE CT OF KCL W/ N2 DUE TO WEIGHT AND MOBILITY ISSUES. TAKE RETURNS TO TIGER TANK 15:30 - 16:30 1.00 RIGD P POST REMOVE TUBULARS FROM PIPESHED FINISH CLEANING PITS 16:30 - 20:00 3.50 RIGD P POST ND BOPE 20:00 - 21:15 1.25 RIGD P POST NUTREE CAP AND TEST. PRESSURE TEST OF TREE CAP PASSED TO 2950 PSI. 21:15 - 00:00 2.75 RIGD P POST PREPARE TO MOVE RIG. CALL FOR VR PLUGS /EXTRA GATE VALVES TO DOUBLE ISOLATE IA AT SURFACE. IA SURFACE PRESSURE IS 150 PSI. OAP IS 140 PSI. TUBING IS ISOLATED WITH TWC. CONTINUED ON DIMS REPORT 10- DEC -09. 12/10/2009 00:00 - 01:00 1.00 RIGD P POST CONTINUED FROM DIMS REPORT 09- DEC -09. TUBING IS ISOLATED WITH TWC. IAP = 150 PSI. OAP = 140 PSI. VALVE CREW ARRIVES. INSTALL VR PLUG AT WELLHEAD UPSTREAM OF EACH IA GATE VALVE. 01:00 - 01:10 0.17 RIGD P POST PJSM FOR MOVING RIG. 01:10 - 01:30 0.33 RIGD P POST JACK UP RIG. MOVE OFF WELL. 01:30 - 02:00 0.50 RIGD P POST CLEAN UP WELL. MOVE MATS AND HERCULITE. RIG RELEASED AT 0200 HRS 12/10/09 ROAD RIG TO MPE -14. Printed: 12/21/2009 10:18:49 AM s • 6 Val-ill BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB W Pad W -25 W -25A Survey: MWD Survey Report - Geographic 08 December, 2009 0 by C'. (.0 .�.. • 411, BAIGIR HUGHES Survey Report - Geographic 0 bp LNTEQ Company -, North America - ALASKA - BP Local Co- ordinate Reference: Well W -25 Project Prudhoe Bay TVD Reference:: W -25 @ 91.00ft (generic drilling rig) 'Site - PB W Pad MD Reference: W -25 @ 91.00ft (generic dulling rig) Weil , W -25 North Reference True Weltbore: W -25A Survey Cateulation Method " : Minimum Curvature Design W -25A - Database: EDM .16 - Anc Prod - WH24P Project Prudhoe Bay, North Slope, UNITED STATES ` Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point I Map Zone: Alaska Zone 04 Using geodetic scale factor Sit PB W Pad, TR - 11 - 12 Site Position: Northing: 5,957,19418ft Latitude: 70° 17' 31.506 N From: Map Easting: 609,919.18ft Longitude: 149° 6' 36.343 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 0.84 ° Well W -25 API No 500292187400 Well Position +N / -S 0.00 ft Northing: 5,959,27299 ft Latitude: 70° 17' 51.680 N +E / -W 0.00 ft Easting: 611,789.00 ft Longitude: 149° 5' 40.953 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 47.83ft 41felibore �; W -25A API No 500292187401 Magnet," Modet Name Sample :pate " - Declination ` fii� Angie Fteld �gth. BGGM2008 3/23/2009 22.60 80.87 57,688 Design "_. W -25A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,095.54 :Vertical Section: t epth From frt. Tty, +N/ -S +Et-W Direction t+ (ft) ( (0)-- 37.76 0.00 0.00 291.39 Sutveype04) tm Date .12/8/2009 From To (ft} .: Suttvey tWstlbore} Tool Name Desi'tption 50.60 10,095.54 1 : Schlumberger GCT multishot (W -25) GCT -MS Schlumberger GCT multishot 10,100.00 11,240.00 MWD (W -25A) MWD MWD - Standard 12/8/2009 11:01:21AM Page 2 COMPASS 2003.16 Build 71 • BARER WS S urvey Report - Geographic 0 bp INTEQ Company:- North America - ALASKA - BP Loca( Co- ordinate Reference Well W -25 Project: Prudhoe Bay TVD Reference: . W -25 @ 91.00ft (generic drilling rig) Site . PB W Pad MD Reference: W -25 @ 91.00ft (generic drilling rig) VYit , W-25 North References' True Weftbore: W -25A Survey Calculation Method: Minimum Curvature Design: W -25A Database: EDM .16 - Anc Prod - WH24P Survey Measured Vertical.: - Mop Map Depth:; inclination Azimut Dept +N! -S +EIW Northing Casting ' ft) l ° ? k tit) eft} (ft) tft3 (ft) Latitude Longitude 10,095.54 36.02 317.13 8,752.49 1,975.64 - 3,411.75 5,961,197.49 608,348.54 70° 18' 11.102 N 149° 7' 20.431W TIP 10,100.00 35.99 317.15 8,756.10 1,977.56 - 3,413.53 5,961,199.39 608,346.73 70° 18' 11.121 N 149° 7 20.483 W KOP 10,116.26 40.12 317.15 8,768.90 1,984.91 - 3,420.35 5,961,206.63 608,339.80 70° 18' 11.194 N 149° 7' 20.681 W 10,130.40 43.12 315.00 8,779.47 1,991.66 - 3,426.86 5,961,213.29 608,33319 70° 18' 11.260 N 149° 7' 20.872 W 10,163.36 48.74 308.50 8,802.40 2,007.36 - 3,444.55 5,961,228.72 608,315.27 70° 18' 11.414 N 149° 7' 21.387 W 10,190.12 53.20 303.50 8,819.25 2,019.55 - 3,461.37 5,961,240.66 608,298.27 70° 18' 11.534 N 149° 7' 21.878 W 10,220.03 56.65 297.02 8,836.45 2,031.85 - 3,482.50 5,961,252.64 608,276.96 70° 18' 11.655 N 149° 7' 22.494 W 10,250.35 60.60 292.65 8,852.24 2,042.69 - 3,505.99 5,961,263.13 608,25331 70° 18' 11.761 N 149° 7' 23.179 W 10,280.15 66.16 289.91 8,865.59 2,052.34 - 3,530.81 5,961,272.41 608,228.36 70° 18' 11.856 N 149° 7' 23.903 W 10,309.54 72.79 288.08 8,875.88 2,061.29 - 3,556.82 5,961,280.97 608,202.22 70° 18' 11.944 N 149° 7' 24.662 W 10,340.20 79.37 288.06 8,883.26 2,070.51 - 3,585.10 5,961,289.77 608,17381 70° 18' 12.035 N 149° 7' 25.486 W 10,372.98 83.97 285.74 8,888.00 2,079.93 - 3,616.12 5,961,298.73 608,142.65 70° 18' 12.127 N 149° 7' 26.391 W 10,402.53 87.20 280.88 8,890.28 2,086.71 - 3,644.78 5,961,305.08 608,113.90 70° 18' 12.194 N 149° 7' 27.227 W 10,431.05 87.73 273.81 8,891.54 2,090.35 - 3,673.02 5,961,308.30 608,085.61 70° 18' 12.229 N 149° 7' 28.050 W 10,465.61 85.58 266.43 8,893.56 2,090.43 - 3,707.50 5,961,307.86 608,051.14 70° 18' 12.230 N 149° 7' 29.056 W 10,494.34 86.44 261.98 8,895.56 2,087.53 - 3,736.00 5,961,304.54 608,022.68 70° 18' 12.201 N 149° 7' 29.887 W 10,521.98 84.53 257.65 8,897.74 2,082.66 - 3,763.11 5,961,299.27 607,995.65 70° 18' 12.153 N 149° 7' 30.677 W 10,550.72 86.87 251.23 8,899.90 2,074.98 - 3,790.71 5,961,291.18 607,968.17 70° 18' 12.078 N 149° 7' 31.482 W 10,579.15 85.26 247.00 8,901.85 2,064.87 - 3,817.20 5,961,280.68 607,941.84 70° 18' 11.978 N 149° 7' 32.254 W 10,607.77 83.76 242.31 8,904.59 2,052.68 - 3,842.94 5,961,268.11 607,916.28 70° 18' 11.858 N 149° 7' 33.004 W 10,638.35 83.57 236.75 8,907.96 2,037.27 - 3,869.12 5,961,252.31 607,890.33 70° 18' 11.706 N 149° 7' 33.767 W 10,668.40 83.08 231.39 8,911.46 2,019.77 - 3,893.28 5,961,234.45 607,866.44 70° 18' 11.534 N 149° 7' 34.472 W 10,699.30 84.00 225.96 8,914.94 1,999.50 - 3,916.33 5,961,213.85 607,84370 70° 18' 11.335 N 149° 7' 35.143 W 10,729.04 84.47 219.92 8,917.93 1,977.85 - 3,936.48 5,961,191.90 607,82388 70° 18' 11.122 N 149° 7' 35.730 W 10,762.47 84.53 214.03 8,921.14 1,951.28 - 3,956.48 5,961,165.03 607,804.27 70° 18' 10.860 N 149° 7 36.313 W 10,791.13 84.99 208.52 8,923.76 1,926.89 - 3,971.29 5,961,140.43 607,789.83 70° 18' 10.620 N 149° 7' 36.745 W 10,822.89 85.02 202.32 8,926.52 1,898.33 - 3,984.87 5,961,111.68 607,776.68 70° 18' 10.339 N 149° 7' 37.140 W 10,852.27 85.97 196.55 8,928.83 1,870.72 - 3,994.61 5,961,083.93 607,767.35 70° 18' 10.068 N 149° 7' 37.424 W 10,886.88 85.48 191.63 8,931.41 1,837.26 - 4,003.01 5,961,050.35 607,759.45 70° 18' 9.739 N 149° 7' 37.668 W 10,917.32 83.97 185.28 8,934.22 1,807.29 - 4,007.46 5,961,020.32 607,755.44 70° 18' 9.444 N 149° 7' 37.798 W 10,946.42 85.67 179.73 8,936.85 1,778.35 - 4,008.73 5,960,991.37 607,754.61 70° 18' 9.159 N 149° 7' 37.834 W 10,976.75 83.51 175.20 8,939.71 1,748.20 - 4,007.40 5,960,961.24 607,756.39 70° 18' 8.863 N 149° 7' 37.795 W 11,005.19 83.63 167.95 8,942.90 1,720.26 - 4,003.26 5,960,933.37 607,760.94 70° 18' 8.588 N 149° 7' 37.674 W 11,034.77 83.79 161.07 8,946.14 1,691.94 - 3,995.41 5,960,905.17 607,769.21 70° 18' 8.309 N 149° 7' 37.444 W 11,064.38 82.64 156.66 8,949.64 1,664.52 - 3,984.81 5,960,877.92 607,780.21 70° 18' 8.040 N 149° 7' 37.135 W 11,093.10 77.29 152.21 8,954.65 1,639.02 - 3,972.62 5,960,852.60 607,792.78 70° 18' 7.789 N 149° 7' 36.779 W 11,124.08 72.70 149.84 8,962.66 1,612.85 - 3,958.14 5,960,826.65 607,807.65 70° 18' 7.532 N 149° 7' 36.356 W 11,153.14 68.59 146.69 8,972.30 1,589.54 - 3,943.73 5,960,803.56 607,822.40 70° 18' 7.303 N 149° 7' 35.936 W 11,182.73 63.64 144.68 8,984.27 1,567.19 - 3,928.49 5,960,781.44 607,837.97 70° 18' 7.083 N 149° 7' 35.491 W 11,204.83 58.96 143.30 8,994.88 1,551.51 - 3,917.10 5,960,765.94 607,849.59 70° 18' 6.929 N 149° 7' 35.159 W 11,240.00 58.96 143.30 9,013.02 1,527.35 - 3,899.09 5,960,742.05 607,867.95 70° 18' 6.691 N 149° 7' 34.634 W 2.375" 12/8/2009 11:01:21AM Page 3 COMPASS 2003.16 Build 71 TREE = a -1 /8 "MCEV OY 5000# WELLHEAD = MCEVOY TES: TBGX IA COMM * * *2 -3/8" ACTUATOR = OTIS J MD DRAT 5A CHROMBTBG** *WELL ANGLE> 70° @ 10310' * ** KB. ELEV = 90.74' BF. ELEV = 54.54' 1 KOP = '2800' I 2066' I — I OTIS SSSV LANDING NIP, ID = 2.750" I Max Angle = 88° @ 10431' Datum MD = 10418' • Datum TVD = 8800' SS GAS LIFT MANDRELS 13 3/8" CSG, 68 #, NT -80 BTRS, ID = 12.415" H 2676' ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2985 2984 4 MERLA DMY RM 0 06/22/09 4 6394 5838 44 MERLA DMY RM 0 06/22/09 3 8253 7272 37 MERLA DMY RM 0 05/06/05 2 9386 8179 36 MERLA DMY RM 0 Minimum ID = 2.250" @ 9624' 1 9604 8356 36 MERLA DMY RM 0 05/06/05 BKR DEPLOYMENT SLEEVE � �� 9624' H2.70" 2.70" BLR DEPLOYMENT SLV, ID = 2.250" 1 1 1 1 , I 969T H3 -1/2" OTIS SLIDING SLV, ID = 2.750" I LI I II ■' � 7/, 4v4, v1 v1 9700' H EST TOP OF CEMENT (07/16/06) I X1 1 •! ? H TUBING SEAL ASSEMBLY 1 # 1 4 / , 1 ►�� X 1.0 11 ►.� 9742' I--I 9 -5/8" X 3 TIW PKR, ID = 4.00" I 7 1'1 X 10 ITi 11 11 11 9803' H3-1/2" PARKER X NIP, ID = 2.75" I • TOP OF 7" LNR H 9813' 111 1 1 00'4' 111 1 / 1 1 1 t 1 1 I 9835' 1-13-1/2" PARKER X NIP, ID = 2.75" I 4 4 41 Behind / . 1 ∎ • 1 � 9869' 3 -1/2" TM✓ WLEG, ID = 2.992" 13 -1/2" TBG, 9.3 #, L -80, .0087 bpf, ID = 2.992" H 9869' . 4101 (� I j LN /1 X1 1 O I 987T 1 ELMD TT LOGGED ? ? / ? ?/ ?? I 1144 V1•• •4 111.1 " :1 '' 9900' H EST BOTTOM OF CEMENT (07/16/06) I 11 1 1 9 - 5/8" CSG, 47 #, L - 80, NSCC, ID = 8.681" H 10085' I ∎ ; 1 ; 1 ► ; 1 ; 1 001 10 11111 111111 MILLOUT WINDOW (W -25A) 10100' - 10105' I PILOT HOLE WHIPSTOCK H 10100' •1 11 tO 17" LNR, 26 #, L - 80 IJ4S, .0383 bpf, ID = 6.276" I 10100' V. •1111111• 0 ,• • • • • • • • • • • • • 4 , 1 1 • 1 1 1 • 1 • 1 • 1 ♦ 1111111 1 1 ` 14 PERFORATION SUMMARY •1 ,�1 REF LOG: BHI MWD GR/MPR ON 12/03/09 • • • • • • ` *4 ANGLE AT TOP PER♦: 76° @ 10325' ' , ' , Note: Refer to Production DB for historical perf data ∎ SIZE SPF INTERVAL Opn /Sqz DATE 1.1.1.1.1.1.1.1. 1.56" 6 10325 - 10370 0 12/08/09 1.56" 6 10390 - 10400 0 12/08/09 1 PBTD (LOGGED 12/08/09) 1 11187' ai�0� 1.56" 6 10540 - 10625 0 12/08/09 " : 1.56" 6 10645 - 10905 0 12/08/09 1.56" 6 10930 - 10970 0 12/08/09 12 -3/8" LNR, 4.6 #, 13CR -80, .0039 bpf, ID = 1.995" I 11220' 1.56" 6 10990 - 11070 0 12/08/09 1.56" 6 11095 - 11105 0 12/08/09 1.56" 6 11125 - 11145 0 12/08/09 1.56" 6 11160 - 11175 0 12/08/09 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/10/88 ORIGINAL COMPLETION WELL: W -25A 12/09/09 NORDIC 2 CTD SIDETRACK (W -25A) PERMIT No: '2091020 12/12/09 SV DRLG HO CORRECTIONS API No: 50- 029 - 21874 -01 -00 12/21/09 ? /JMD DRLG DRAFT CORRECTIONS SEC 21, T11 N, R12E, 980' FNL & 1446' FEL BP Exploration (Alaska) • SEAN PA L � � I t,U) i RNELL, GOVERNOR ALASKA OIL AND GAS I 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ° ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 r FAX (907) 276 -7542 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU W -25A BP Exploration (Alaska) Inc. Permit No: 209 -102 Surface Location: 980' FNL, 1446' FEL, SEC. 21, T11N, R12E, UM Bottomhole Location: 528' FSL, 5209 FEL, SEC. 16, T11N, R12E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. 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). Sincerely, athy ' . F erster Com issioner DATED this ZJ day of September, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA DF ALASKr. IL AND GAS CONSERVATION COMMIAN x ` PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work: 1 b. Proposed Well Class: , ® Development Oil ❑ Service - Winj ❑ Single Zone 1 c. Specify if welt is proposed for: ❑ Drill ® Redrill ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re -Entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas 2. Operator Name: 5. Bond: IS Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU W - 25A 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 - 6612 MD 11274' TVD 8945'ss Prudhoe Bay Field / Prudhoe 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Bay Oil Pool Surface: ADL 028263 980' FNL, 1446' FEL, SEC. 21, T11 N, R12E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1062' FSL, 4914' FEL, SEC. 16, T11 N, R12E, UM November 5, 2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 528' FSL, 5209' FEL, SEC. 16, T11 N, R12E, UM 2560 15,396' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 91' feet 15. Distance to Nearest Well Open Surface: x- 611789 y- 5959273 Zone- ASP4 GL Elevation above MSL: 53.24' feet to Same Pool: 1,496 16. Deviated Wells: Kickoff Depth: 10114 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 87 degrees Downhole: 3600 Surface: 2720 18. Casing Program: Specifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2 - 3/8" 4.7# Cr80 STL , 1342' 9820' 8439'ss 11274' 8945'ss 42 cu ft Class 'G' . 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re - entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 10650' 9213' None 10608' 9178' 10600' Casing Length Size Cement Volume MD TVD Conductor / Structural 110' 20" 8 cu vds Concrete 110' 110' Surface 2674 13 -3/8" 1920 cu ft Coldset III. 1922 cu ft Coldset 11 2674' 2674' Intermediate 10085' 9 -5/8" 1528 cu ft Class 'G'. 585 cu ft Class 'G' 10085' 8744' Production Liner 837' 7" 304 cu ft Class 'G' 9813' - 10650' 8524' - 9213' Perforation Depth MD (ft): 10256' - 10458' Perforation Depth TVD (ft): 8884' - 9053' 20. Attachments: ❑ Property Plat . BOP Sketch 0 Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter 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. Contact Ron Phillips, 564 -5913 Printed Name Jo. .., « Title Engineering Team Leader _dr AI/ q � � Prepared By Name/Number Signature / . Phone 564 -4711 Date 2 � Terrie Hubble, 564 -4628 r Commission Use Only Permit To Drill API Number: Pert ,.• pr• v I D ate : See cover letter for Number: (0 ,109,a,7 50- 029 - 21874 -01 -00 7 4 i other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed ,�etthhane, gas hydrates, or gas contained shales: Other: go �cS� Samples Req'd: Yes IYJ No Mud Log Req'd: ❑ Yes No 35 o p ' \ H Measures: I Yes ❑ No Directional Survey Req'd: " ' Yes ❑ No 25c e , Ahh ‘4.14.1- es f / `— ' 9 l/ -v / 0 THE COMMISSION Date C/ l _ APPROVED BY COMMISSIONER Form 10-401 Revised 07/2009 CriReInGsivr f months from the ate oapproval (20 AAC 25.005(g)) Submit In Duplicate 0 • , ., �bp To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Ron Phillips, CTD Engineer Date: September 16, 2009 Re: Prudhoe Bay W -25A Permit to Drill Request The sidetrack, W -25A, is scheduled to be drilled by Nordic 2 around November 5, 2009. The plan calls for a slimhole lateral with a solid liner and 500 ft of P erforations. Pre -Rig Work: The pre CTD work is slated to begin on October 5, 2009. 1. S Dummy GLV's 2. S Dummy WS drift to tubing tail. (Note: several 2.75" restrictions in well) 3. W MIT -IA to 3000 psi 4. C Lay in 17# kick off plug from PBTD, wash down to the tubing tail (50 bbl of cement) 5. W AC -LDS; AC- PPPOT -T 6. W PT tree (MV,SV,WV) 7. 0 Bleed gas lift and production flowlines down to zero and blind flange 8. 0 Remove S- Riser, Remove wellhouse, level pad. Rig Work: Spud . November 5, 2009 S"bk+1o 1. MIRU and test BOPE to 250 psi low and 3500 psi high 36y 3`fl 2. Drill 2.74" pilot hole in cement to 10,130'. 3. Run dummy whipstock drift 4. Set whipstock highside at 10,100' 5. Mill 2.74" window and 10' of openhole. Swap the well to Geo -VIS 6. Drill Lateral: 3" OH, 1,174' horizontal (20 °/100 planned). 7. Run 2 -3/8" solid liner leaving TOL at 9820'. '' 8. Pump primary cement job, TOC at liner top. (7.4 bbls of cement) Prb 9. Run CO assembly Avg_ /o2- 10. Run GR/CCL log 11. Test liner lap to 2000 psi. 12. Perforate, planned 500'. 13. If needed set Liner top packer. 14. Freeze protect well, Set BPV, RDMO Post -Rig Work 1. Re- install wellhouse and FL's. 2. Pull BPV. 3. Run gas lift design 4. POP Well, 500' of planned perfs. • • Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Geo -Vis or biozan for milling, new Geo -Vis for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3" Casing Program: • 2 3/8 ", 4.7# , Cr -80, STL connection Solid liner — 11,274' to 9,820'. • A minimum of 7.4 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 9,820 ft (liner top). Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 87 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property — 15,396 ft (W) • Distance to nearest well within pool — 1,496' ft to W -31A Anticollision Summary • No close approaches Logging • MWD directional and Gamma Ray will be run over all of the open hole section. Hazards • The maximum recorded H2S level on W pad is 56 ppm. • No mapped faults cross this wellbore. • Lost circulation risk is low to med. Reservoir Pressure • Res. press. is estimated to be 3,600 psi at 8,800'ss (7.9ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2720 psi. Ron Phillips CTD Drilling Engineer 564 -5913 CC: Well File Sondra Stewman/Terrie Hubble TREE= 3- 1 /8 "MCEVOY 5000# WELLHEAD'= MCEVOY • W -2 5 0 SAFETY NOTES: I ACTUATOR = OTIS KB. ELEV = 90.74' BF. ELEV = 54.54' KOP = 2800' Max Angle = 46 5996' 2065' OTIS SSSV LANDING NIP, D = 2.750" Datum MD = 10264' III ( H Datum TV D = 8800' SS GAS LIFT MANDRELS ST I MD I TVD I DEV I TYPE I VLV I LATCHI PORT DATE 113 -3/8" CSG, 68#, NT-80 BTRS, D = 12.415" H 2676' I--• II I 5 2985 2984 4 MERLA DOLE RM 16 07/21/06 4 6394 5838 44 MERLA SO RM 20 07/21/06 3 8253 7272 37 MERLA DMY RM 0 05/06/05 2 9386 8179 36 MERLA DMY RM 0 Minimum ID = 2.75" © 2065' 1 9604 8356 36 MERLA DMY RM 0 05/06/05 OTIS SSSV LANDING NIPPLE I I I 9697' H3 -1/2" OTIS SLIDING SLV, D = 2.750" I �/� '.:1 9700' H EST TOP OF CEMENT (07/16/06) I ? HTUBING SEAL ASSEMBLY J 1 3.:11 ∎�� 9742' — 19 -5/8" X 3-1/2" TAN PKR, ID = 4.00" I v irs • • • • ► # / 1 (TOP OF7"LNR H 9612' »/ »» j 9802' H3- 1 /2 " PARKER X NP, D =2.75" I •/ I 1 A/ 1'0) 9835 H3-1/2" PARKER X NP, 0 = 2.75" 1 X 1 ►�•1 3 -1/2" TBG, 9.3#, L-80, .0087 bpf, 0 = 2.992" 9868' • a / t • 3-1/2" TAN WLEG, D = 2.992" • 1 � 1 9877' H ELMD TT LOGGED ??/??/?? I A 1t.: 9900' HEST BOTTOM OF CEV s1T (07/16/06) I 19 -5/8" CSG, 47 #, L -80, NSCC, D = 8.681" H 10085' 1 10177' H MARKER JOINT I PERFORATION SUMMARY RE= LOG: BHCS ON 11/04/89 , ANGLE AT TOP PERF: 34° @ 10256' , Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1 2 -1/4" 6 10256 - 10266 0 01/27/08 1 2 -1/4" 6 10275 - 10302 0 01/27/08 , 2 -1/2" 4 10310 - 10317 0 03/12/01 2 -1/2" 6 10327 - 10335 0 08/08/03 1 2 -1/2" 6 10341 - 10361 0 08/08/03 1 5" 4 10359 - 10377 0 09/24/89 , 5" 4 10382 - 10408 0 09/24/89 , 2 -5/8" 4 10424 - 10432 0 04/30/90 2 -5/8" 4 10444 - 10458 0 04/30/90 10600' H FISH - JUNK 2.5" X 8" PRK RUBBER 1 1 10605' HASH - 2.5" 4" PKR I Perm H 10608' .- •• -••- 1 * * * 17" LNR, 26#, L -80 U4S, .0383 bpf, D = 6.276" H 10650 4. DATE REV BY COMMENTS DATE REV BY CONSENTS PRUDHOE BAY UNIT 11/10/88 ORIGINAL COMPLETION 07/21/06 CJNIPJC GLV C/O WELL: W -25 08/08/03 BJANTLP ADD PERFS 01/17/08 DGD/PJC GLV CORRECTIONS PERMIT No: 1881170 01/10/05 DBRITLP ADD MISSING 08/08/03 PERFS 02/02/08 TEL/SV ADD PERF (01/27/08) API No: 50- 029 - 21874 -00 12/20/04 SGS/PJC CORRECTION PERFS SEC 16, T11 N, R12E, 980' SNL & 1446' WEL 04/03/06 JCMIPJC PULL TTP @ 969T 107/16/06 JGMPJC_CENENT BP Exploration (Alaska) TREE = 3 -1 /8 "MCEV OY 5000# WELLHEAD = MCEVOY i VV-25A • SAFETY NOTES: ACTUATOR = OTIS Proposed CTD Sidetrack KB. ELEV = 90.74' BF. ELEV = 54.54' KOP = 2800' Max Angle = 46 @ 5996' Datum MD = 10264' ( I 2065' H OTIS SSSV LANDING NIP, ID = 2 750" I Datum TV D = 8800' SS O GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13 -3/8" CSG, 68 #, NT -80 BTRS, ID = 12.415" H 2676' I-- 5 2985 2984 4 MERLA DOME RM 16 07/21/06 4 6394 5838 44 MERLA SO RM 20 07/21/06 3 8253 7272 37 MERLA DMY RM 0 05/06/05 2 9386 8179 36 MERLA DMY RM 0 Minimum ID = 1.969" @ TOL 1 9604 8356 36 MERLA DMY RM 0 05/06/05 Baker deployment sly I 9697' H3 -1/2" OTIS SLIDING SLV, ID = 2.750" I ' . A ., 9700' H EST TOP OF CEMENT (07/16/06) I I C I 144 ? H TUBING SEAL ASSEMBLY M� ∎� 9742' 1-19-5/8" X 3 -1/2" TIW PKR, ID = 4.00" I 4-47 4 1.1 ITOPOF7" LNR H 9812' 4 , 1 1/ H2.70" H3-1/2" PA RKER X NIP, ID = 2.75" I " ,/ /. I 9820' 2.70" BKR DEPLOYMENT SLV, ID = 1.969" I '• VII 9835 3 -1/2" PARKERX NIP, ID = 2.75" 11 111 13 -1/2" TBG, 9.3 #, L -80, .0087 bpf, ID = 2.992" H 9868' �� It 9868' (- 13 -1/2" TNV WLEG, ID = 2.992" I hi 4 9900' H EST BOTTOM OF CEMENT (07/16/06) I 19 -5/8" CSG, 47 #, L -80, NSCC, ID = 8.681" H 10085' I-- ' I Hlot Hole 2ih,rstoc H 10100' I 36il PERFORATION SUMMARY REF LOG: BHCS ON 11/04/89 I 2 -3/8" LNR, 4.6 #, 13CR80, .0039 bpf, ID = 1.941" I-1 11274' I ANGLE AT TOP PERF: 34° @ 10256' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2-1/4" 6 10256 - 10266 0 01/27/08 2 -1/4" 6 10275 -10302 0 01/27/08 2 -1/2" 4 10310 -10317 0 03/12/01 2 -1/2" 6 10327 - 10335 0 08/08/03 2 -1/2" 6 10341 - 10361 0 08/08/03 5" 4 10359 - 10377 0 09/24/89 5" 4 10382 - 10408 0 09/24/89 2 -5/8" 4 10424 - 10432 0 04/30/90 2 -5/8" 4 10444 - 10458 0 04/30/90 17" LNR, 26 #, L -80 U4S, .0383 bpf, ID = 6.276" I 10650' M DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/10/88 ORIGINAL COMPLETION 1 07/21/06 CJN/PJC GLV 0/0 WELL: W -25'+ 08/08/03 BJM/TLP ADD PERFS ; 01/17/08 DGD /PJC GLV CORRECTIONS PERMIT No: 01/10/05 DBR/TLP ADD MISSING 08/08/03 PERFS 1 02/02/08 TEL /SV ADD PERF (01/27/08) API No: 50- 029 - 21874 -0' 12/20/04 SGS /PJC CORRECTION PERFS 02/17/09 MSE PROPOSED CTD SIDETRACK SEC 16, T11 N, R12E, 980' SNL & 1446' WEL 04/03/06 JCM/PJC PULL TTP @ 9697' 6 07/16/06 JGM/PJC CEMENT BP Exploration (Alaska) • • All Measurements are from top of Riser 9/14/2009 i a) Cr) CC W -25A top of bag Schlumberger BAG bttm of bag middle of blind /shears Blind /Shears i............ I I TOTs I middle of pipes 2" combi pipe /slips I Mud Cross Mud Cross middle of flow cross [ I I middle of rams I 2 3/8" x 3 1/2" VBR's I I TOTs I middle of pipe /slips 2" combi pipe /slips I 1 Swab Valve _ I I Flow Tee mar BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB W Pad W -25 Plan 5, W -25A Plan: Plan 5 Baker Hughes INTEQ Planning Report yip 30 April, 2009 � b p Milt BP Exploration Alaska I Ai '�rss Baker Hughes INTEQ Planning Report bP INTEQ „,„ „„ , „ . „ „ „ , , „ . „ .„ „ , , , „ „ „ , _ „, , ,„„ . _ , „ „ „ „ „ . , .. ° '. ,,,,,,,,,,,,,1 - Company: : ; North America - ALASKA - BP Local Co -ordinate Referencs Well W -25 Projector Prudhoe Bay TVD Reference ; W -25 @ 91.00ft (generic drilling rig) Si PB W Pad MD Reference W -25 @ 91.00ft (generic drilling rig) Well W-25 North Reference True Wellbore Plan 5, W -25A Survey C alculation Method Minimum Curvature Design :, Plan 5 Datab EDM .16 Anc Prod - WH24P Project Prudhoe Bay North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PBWPad,TR1112 Site Position: Northing: 5,957,194.18 ft Latitude: 70° 17' 31.506 N From: Map Easting: 609,919.18 ft Longitude: 149° 6' 36.343 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 0.84 ° Well W -25, W -25 Well Position +N / -S 0.00 ft Northing: 5,959,272.99 ft Latitude: 70° 17' 51.680 N +E / -W 0.00 ft Easting: 611,789.00 ft Longitude: 149° 5 40.953 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 47.83 ft Wellborn ` Plan 5, W -25A Magnetics Model Name ,Sample ate D � � � „ Declination Dip Angle Field Stre ( °) i � z` En's BGGM2008 3/23/2009 ° . 22.60 80.87 F 57,688 Design m Plan 5 Audit Notes: New, deeper TD at 8945' tvdss Version: Phase: PLAN Tie On Depth: 10,095.54 Vertical Section Depth F (TVD +Nf-S : ` +g/ W ..,. Direction Rj jj ( ° I f , 3 7.76 0.00 0.00 225 .00 4/30/2009 3:08 :34PM Page 2 COMPASS 2003.16 Build 70 Milli s BP Exploration Alaska Baker Hughes INTEQ Planning Report 0 by 1NTEQ Comparny :; North America - ALASKA - BP : ::. Local Co- ordinate Reference:' Well W -25 : Project :. :„ "Prudhoe Bay : ; ) [VD Reference W -25 9100 ft (generic drilling rig Site PB W Pad MD Reference . W -25 @ 91.00ft (generic drilling rig) 'Weil `- W -25 North Reference:° True Wetibore Plan 5, W -25A Survey.Gaiculation Method Minimum Curvature Design Plan 5 Database ' EDM . 16 - Anc Prod - WH24P Survey Tool program., Date 4/30/2009 From To (fk) (ft) Survey(Welihore); Tool Name Description :r 50.60 10,095.54 1 : Schlumberger GCT multishot (W -25) GCT -MS Schlumberger GCT multishot 10,095.54 11,274.10 Plan 5 (Plan 5, W -25A) MWD MWD - Standard "Planned Survey . . MD.- " , . Inc .. . , Azi , , : . . : TVD88:. WS: - E/W Northing ,Easting DLeg V Sec,; TFace ' (ft) . .. O; . ( °) : ., . , ( _ . . , . . (ft :.. ; (ft) ' ? (ft) . -:(ft).' . .:: , ( / : (ft) (1 - 1', - ' , ' : ° 10,095.54 36.02 317.13 8,661.49 1,975.64 - 3,411.75 5,961,1 608,348.54 0.00 1,015.48 0.00 TIP 10,100.00 35.99 317.15 8,665.10 1,977.56 - 3,413.53 5,961,199.39 608,346.73 0.72 1,015.39 158.61 KOP 10,114.00 40.53 311.85 8,676.09 1,983.61 - 3,419.72 5,961,205.35 608,340.45 40.00 1,015.48 -38.00 End 40 Deg /100' DLS 10,200.00 54.92 298.99 8,733.92 2,019.58 - 3,471.71 5,961,240.54 608,287.93 20.00 1,026.81 -38.00 10,300.00 72.79 288.91 8,777.89 2,055.26 - 3,553.52 5,961,274.99 608,205.61 20.00 1,059.43 -29.27 10,366.87 85.00 283.33 8,790.75 2,073.37 - 3,616.43 5,961,292.17 608,142.44 20.00 1,091.10 -24.76 4 10,400.00 84.57 276.69 8,793.77 2,079.11 - 3,648.90 5,961,297.41 608,109.89 20.00 1,110.01 -94.0 10,500.00 83.74 256.60 8,804.05 2,073.33 - 3,747.69 5,961,290.17 608,011.21 20.00 1,183.95 -93.4 10,600.00 83.66 236.48 8,815.14 2,033.97 - 3,838.39 5,961,249.47 607,921.11 20.00 1,275.92 -91.33 10,666.87 84.04 223.03 8,822.33 1,991.12 - 3,889.02 5,961,205.87 607,871.13 20.00 1,342.02 -89.10 5 10,700.00 84.08 216.37 8,825.76 1,965.78 - 3,910.06 5,961,180.23 607,850.47 20.00 1,374.81 -90.00 10,800.00 84.68 196.28 8,835.65 1,877.05 - 3,953.96 5,961,090.86 607,807.90 20.00 1,468.60 -89.31 10,900.00 85.91 176.25 8,843.94 1,778.49 - 3,964.77 5,960,992.16 607,798.56 20.00 1,545.93 -87.32 10,986.87 87.39 158.91 8,849.05 1,694.13 - 3,946.18 5,960,908.09 607,818.39 20.00 1,592.45 -85.66 6 11,000.00 85.71 156.89 8,849.84 1,681.98 - 3,941.25 5,960,896.02 607,823.50 20.00 1,597.55 - 130.00 11,100.00 73.20 140.98 8,868.22 1,598.08 - 3,891.04 5,960,812.88 607,874.95 20.00 1,621.37 - 129.88 • 4/30/2009 3 :08 :34PM Page 3 COMPASS 2003.16 Build 70 • g ii � f,' R tr BP Exploration Alaska Yfi.US Baker Hughes INTEQ Planning Report 0 bp 1NTEQ Company: North America - ALASKA - BP 'Local Co- ordinate Reference Well W -25 Project. .. ,':... . Prudhoe Bay ' TVR Reference 'W @ 91 OOft (generic drilling rig) . Site` , PB W Pad W -25 @ 91.00ft (generic drilling rig) MD Referenaet Wlell W-25 North Reference True libore: Plan 5, W -25A Surve" C� cu Vlie Minimum Curvature y i lation Method Design . ..:; Plan 5 13atabase. EDM 16 Anc Prod WH24P Planned Survey , .' . MDu` < , ,. ` Inc Az TVCSS : itS , .. Northing : Fasting Dteg Vf Sec 1'Face (ft .): " ; , . ('i = ( °) (ft) . (ft} (ftY ( ft) (ft) .... : ..... : ( °1iOOft): (fti ..:........ (0 : ...... 11,200.00 62.07 122.96 8,906.47 1,536.23 - 3,823.15 5,960,752.05 607,943.75 20.00 1,617.10 - 126.93 11,274.10 55.55 107.37 8,945.00 1,509.14 - 3,766.21 5,960,725.82 608,001.09 20.00 1,595.98 - 119.9 TD - 2 3/8" • 4/30/2009 3 :08 :34PM Page 4 COMPASS 2003.16 Build 70 /A 11111 BP Exploration Alaska s Baker Hughes INTEQ Planning Report bp 1NTEQ Company. 3 North America - ALASKA - BP , L ocal Coordinate deference Well W -25 ii Project Prudhoe Bay ND Reference: W -25 @ 91.00ft (generic drilling rig) r : to ' PB W Pad MD Reference W -25 © 91.00ft (generic drilling rig) Well W -25 yWeflbore Plan 5, W -25A Survey Calculation Method Minimum Curvature resign : Plan 5 Database ,: EDM .16 Anc Prod - WH24P Target Name hlttmiss DlpAngle DlpDlr . ; ND . *N/ +E/W Northing Fasting Shape ( °) O (ft) , ; {ft)' : < ( (ft). _ :: (ft) ... ' L itu4 . l. ongit d® W -25A Hardline - stay 0.00 0.00 91.00 1,654.12 - 4,490.28 5,960,860.00 607,275.00 70°18' 7.935 N 149° 7' 51.872 W - plan misses target center by 8734.30ft at 10095.54ft MD (8752.49 ND, 1975.64 N, - 3411.75 E) - Polygon Point 1 91.00 1,654.12 - 4,490.28 5,960,860.00 607,275.00 Point 2 91.00 1,559.14 - 4,156.63 5,960,770.00 607,610.00 Point 3 91.00 1,387.99 - 3,409.03 5,960,610.00 608,360.00 Point 4 91.00 1,559.14 - 4,156.63 5,960,770.00 607,610.00 W -25A Target 2 0.00 0.00 8,941.00 1,679.95 - 3,940.79 5,960,894.00 607,824.00 70° 18' 8.192 N 149° 7' 35.851 W - plan hits target center - Point W- 25A Target 1 0.00 0.00 8,881.00 2,072.11 - 3,609.89 5,961,291.00 608,149.00 70° 18' 12.050 N 149° 7' 26.209 W - plan hits target center - Point W -25A fault 2 0.00 0.00 91.00 2,498.92 - 4,465.71 5,961,705.00 607,287.00 70° 18' 16.243 N 149° 7' 51.170 W - plan misses target center by 8741.O6ft at 10095.54ft MD (8752.49 TVD, 1975.64 N, - 3411.75 E) - Polygon Point 1 91.00 2,498.92 - 4,465.71 5,961,705.00 607,287.00 Point 2 91.00 1,319.44 - 4,516.26 5,960,525.00 607,254.00 W -25A Target 3 0.00 0.00 8,981.00 1,556.59 - 3,850.60 5,960,772.00 607,916.00 70° 18' 6.979 N 149° 7' 33.220 W - plan hits target center - Point W- 25A fault 3 0.00 0.00 91.00 1,377.28 - 4,571.41 5,960,582.00 607,198.00 70° 18' 5.211 N 149° 7' 54.233 W - plan misses target center by 8759.24ft at 10095.54ft MD (8752.49 TVD, 1975.64 N, - 3411.75 E) - Polygon Point 1 91.00 1,377.28 - 4,571.41 5,960,582.00 607,198.00 Point 2 91.00 1,251.03 - 4,220.22 5,960,461.00 607,551.00 Point 3 91.00 1,086.61 - 3,387.50 5,960,309.00 608,386.00 Point 4 91.00 973.52 - 3,248.16 5,960,198.00 608,527.00 Point 5 91.00 1,086.61 - 3,387.50 5,960,309.00 608,386.00 Point 6 91.00 1,251.03 -4,220.22 5,960,461.00 607,551.00 W -25A fault 4 0.00 0.00 91.00 917.51 - 3,316.00 5,960,141.00 608,460.00 70° 18' 0.696 N 149° 7' 17.625 W - plan misses target center by 8726.41ft at 10095.54ft MD (8752.49 ND, 1975.64 N, - 3411.75 E) - Polygon 4/30/2009 3 :08 :34PM Page 5 COMPASS 2003.16 Build 70 ,ii BP Exploration Alaska e8 Baker Hughes INTEQ Planning Report 0 bp 1NTEQ , Company: ' North America - ALASKA - BP •: -LOOM. Coordinate :Reference Well W -25 ProJo t.., , Prudhoe Bay ND Ridf rence W-25 © 91.00ft (generic drilling rig) PB W Pad MD Reference W -25 @ 91.00ft (generic drilling rig) Weil W -25 '' ` North Reference:. True ".:Welibore; ` ` Plan 5, W -25A Survey Calculation Method Minimum Curvature Resign : Plan 5 . ' .; '%',.:...': . :-.: . ,':-...;.;;:': - .:-"„-- ',.' ' ,; --.: ',..: Databas :. EDM .16 - Anc Prod - WH24P Point 1 91.00 917.51 -3,316.00 5,960,141.00 608,460.00 Point 2 91.00 1,353.18 - 3,355.53 5,960,576.00 608,414.00 Point 3 91.00 1,829.17 - 3,348.45 5,961,052.00 608,414.00 Point 4 91.00 1,353.18 - 3,355.53 5,960,576.00 608,414.00 W -25A fault 1 0.00 0.00 91.00 2,421.07 - 4,543.88 5,961,626.00 607,210.00 70° 18' 15.477 N 149° 7' 53.449 W - plan misses target center by 8746.52ft at 10095.54ft MD (8752.49 ND, 1975.64 N, - 3411.75 E) - Polygon Point 1 91.00 2,421.07 - 4,543.88 5,961,626.00 607,210.00 Point 2 91.00 2,380.00 - 4,472.48 5,961,586.00 607,282.00 Point 3 91.00 2,362.47 - 4,033.65 5,961,575.00 607,721.00 Point4 91.00 2,544.89 - 3,655.86 5,961,763.00 608,096.00 Point 5 91.00 2,275.27 - 3,348.81 5,961,498.00 608,407.00 Point 6 91.00 2,544.89 - 3,655.86 5,961,763.00 608,096.00 Point 7 91.00 2,362.47 - 4,033.65 5,961,575.00 607,721.00 Point 8 91.00 2,380.00 - 4,472.48 5,961,586.00 607,282.00 W -25A Polygon 0.00 0.00 91.00 1,882.63 - 3,445.67 5,961,104.00 608,316.00 70° 18' 10.188 N 149° 7' 21.419 W - plan misses target center by 8662.06ft at 10095.54ft MD (8752.49 ND, 1975.64 N, - 3411.75 E) - Polygon Point 1 91.00 1,882.63 - 3,445.67 5,961,104.00 608,316.00 Point 2 91.00 2,033.21 - 3,348.41 5,961,256.00 608,411.00 Point 3 91.00 2,142.56 - 3,504.82 5,961,363.00 608,253.00 Point4 91.00 2,195.28 - 3,687.07 5,961,413.00 608,070.00 Point 5 91.00 2,157.92 - 3,864.66 5,961,373.00 607,893.00 Point 6 91.00 2,050.73 - 3,988.28 5,961,264.00 607,771.00 i Point 7 91.00 1,912.90 - 4,068.34 5,961,125.00 607,693.00 Point 8 91.00 1,737.01 - 4,077.96 5,960,949.00 607,686.00 Point 9 91.00 1,538.73 - 3,994.89 5,960,752.00 607,772.00 Point 10 91.00 1,464.14 - 3,686.94 5,960,682.00 608,081.00 Point 11 91.00 1,690.38 - 3,834.61 5,960,906.00 607,930.00 Point 12 91.00 1,854.73 - 3,856.17 5,961,070.00 607,906.00 Point 13 91.00 1,970.33 - 3,760.43 5,961,187.00 608,000.00 Point 14 91.00 1,967.90 - 3,597.43 5,961,187.00 608,163.00 4/30/2009 3:08:34PM Page 6 COMPASS 2003.16 Build 70 Vali II BP Exploration Alaska sees Baker Hughes INTEQ Planning Report 0 bP , 1NTEQ North America - ALASKA - BP Looal Co rdinate Reference .. Well W -25 . Company, . Project . , 'Prudhoe Bay D Rererence, ? . ' W -25 @ 91.00ft (generic drilling rig) S1te , ; PB W Pad -- .. 1 (generic drilling MD I�eference: -'= - W-25 @ 9 ft e ' 'n ri g) Well ' -.. . , W -25 North Reference True Ilbore Plan 5, W -25A Survey Calculation Method Minimum Curvature Deslgn: , Plan 5 :' Databa a EDM .16 Anc Prod - WH24P 'Casing Poi .a Measured Vertical a Casin Hole Depth Depth ; Diameter Diameter . ... -' 1), . . , .. .... (R) .. ` . Name :.. .. : ... .' . (in) (in. ' ..: 11,274.10 9,036.00 2 3/8" 2.375 3.000 2,676.00 2,675.96 13 3/8" 13.375 17.500 10,085.00 8,743.97 9 5/8" 9.625 12.250 Plan Annotations Measured , .:Vertical Local Coordinates". .. .. : Depth: Depth .+NI -$ .. ' . +EJ- 10,095.54 8,752.49 1,975.64 - 3,411.75 TIP 10,100.00 8,756.10 1,977.56 - 3,413.53 KOP 10,114.00 8,767.09 1,983.61 - 3,419.72 End 40 Deg /100' DLS 10,366.87 8,881.75 2,073.37 - 3,616.43 4 10,666.87 8,913.33 1,991.12 - 3,889.02 5 10,986.87 8,940.05 1,694.13 - 3,946.18 6 11,274.10 9,036.00 1,509.14 - 3,766.21 TD I Checked By: Approved By: Date: 4/30/2009 3:08:34PM Page 7 COMPASS 2003.16 Build 70 Az�mwha t Tme Nona WELLBORE DETAILS: Plan 5 , W -25A REFERENCE INFORMATION Id ill Project: Prudhoe Bay Ma gnetic North: 2280' ' True North Site: PB W Pad Co-ordinate (N /E) Reference: Well W -25, Tr BAKER Magnetc Field Parent Wellbore: W -25 Te on MD: 10095.54 0 bp Well: W -25 Strength. 57699.2en7 Vertical (TVD) Reference: Mean Sea Level Wellbore: Plan 5, W -25A Dip angle' eo.er• Sedbn (VS) Reference: Mot - (O.00N, 08 (generk 0.00E) P lea: Plan 5 (W-25/Plan 5, W -25A) ModeI�BG°M20o9 Measured Depth Reference: W -25 ® 91.0 ddling rig) Calalatbn Method: Minimum Curvature INTEQ 2400 WELL DETAILS: W -25 2325 Ground Level: 47.83 +N / -S +E / -W Northing Easting Latittude Longitude Slot 2250 0.00 0.00 5959272.99 611789.00 70° 17' 51.680 N 149° 5' 40.953 W SECTION DETAILS ANNOTATIONS 2175 r Bet 1 Sec MD Inc Ali ssTVD +N / -S +E / -W DLeg TFace VSec Target Annotation 2100" 1 10095.54 36.02 317.13 8661.49 1975.64 -3411.75 0.00 0.00 1015.48 TIP j IIiI 4111111111111116 � 3 2 101114.00 40.53 311.85 86 35.99 76.09 1983.61 - 3419.72 40.00 1 32 2 00 1015.48 E d 40 Deg /100' DLS ^ 2025 , 4 10366.87 85.00 283.33 8790.75 2073.37 - 3616.43 20.00 322.00 1091.10 4 1950 ,.�� A .. 5 10666.87 84.04 223.03 8822.33 1991.12 - 3889.02 20.00 266.00 1342.02 5 „ ®,_ 158 6 10986.87 87.39 158.91 8849.05 1694.13 3946.1 1 B 20.00 270.00 1592.45 6 s � , 7 11274.10 55.55 107.37 8945.00 1509.14 - 3766.21 20.00 230.00 1595.98 TD 1875 nd 4C Deg/111 t • KOP • .r 1800" 0 1725 1650 -��sii.■■' ,11' 1575. 11 =1■■' 1500 - ' W -25/P • , 1425 1111111111111 1350 1275 -4275 -4200 -4125 -4050 -3975 -3900 -3825 -3750 -3675 -3600 -3525 -3450 -3375 -3300 -3225 -3150 -3075 -3000 -2925 West( - )/East( +) (75 ft/in) 8640. 9 5/8" 8670 111' � , ' . 8700 KOP 11 E ad 40 Deg/ 100' DLS O 8730 M I -°-9' 8760_ W -2`A riegel - 1 , i d) N ca - 8790 Si 4 U c 8820 W -2 -A target 2 • " m 0 2 5 8858 ---.' 6 W -25A Target 3 e 8880 H 8910 1 • 894 1 - - W-25 Plan 5 W -25A TO 840 870 900 930 960 990 1020 1050 1080 1110 1140 1170 1200 1230 1260 1290 1320 1350 1380 1410 1440 1470 1500 1530 1560 1590 1620 1650 1680 1740 1770 1800 1830 1860 1890 1920 1950 1980 2010 Vertical Section at 225.00° (30 ft/in) . 1 • Aameme to Trve �^^ WELLBORE DETAILS: Plan 5, W -25A REFERENCE INFORMATION Project: Prudhoe Bay Magrrolic Nrrrd,: zzr>o° NMI Site: PB W Pad Co (N /E) Reference: Well W - 25. True North BAKER Magnetic veld Parent Wellbore: W - 25 0 bp Well: W - Strength 5 Veeral (TVD) Reference: W -25 (91.00f1(genedc ddling dg) NVQ �je Dip Angle: 688 Tie on MD: 10095.54 Section (VS) Reference: Slot - (0.00N, 0.00E) •7 Wellbore: Plan 5, W - 25A ( ) P lan: Plan 5 (W 5, W - 25A Da.: le: 80. 7° Measured Depth Reference: W-25 91.006 (generic ddling d9) M otlel: BGGM200e Cakulatbn Method: Minimum Curvature INTEQ O� 27,1 ` O lzn W -33) 'Ian W-49 � 1 ' -26/ N -26 k ,' III 2700 . % - N 2.•1 imimiupliii „ - , , , w.5c, 2580 2520 ` 24.ir InIIIIIIIMIIIImadkfr - ,, 2400 23 ` 1 . 2280 2220 ^ 216 0: ' 1111111111111111111111111 Q lig, 4 2100 2 �. \ / + 1980 , �O G 1920 hh 0 4 1860 1800 � 4rVh 1740 1680 , 4r h ° 1620. -..._ ■.■-I_ ^ O 1500• .m'� ► =�� I_ O 1440. 1 �■''�..�I_ ^O 1381 • 11 ■■■■■-maxim 1320 W - 3 /W �'' .■■■■-■.■- ',.. 1260 11111 ■■■ 1200 i , h �...MEM 1 Oft (generic drilling ri�_ _ .. - . ■- -.■■ - '_ 1140' \- _IIIIM - - - -_Mll11; M M- -4800 -4740 -4680 -4620 -4560 -4500 -4440 -4380 -4320 -4260 -4200 -4140 -4080 -4020 -3960 -3900 -3840 -3780 -3720 -3660 -3600 -3540 -3480 -3420 -3360 -3300 -3240 -3180 -3120 -3060 -3000 -2940 -2880 -2820 -2760 -2700 -2640 -2580 West( - )/East( +) (60 ft/in) ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 50.00 NORTH AMERICA HUMES 4 : 6 0) bp Depth Range From: 10095.54 To 1127410 Results Limited By: Centre Distance: 1323.63 ern tre" r = c ''' ' ''' Wellbore: Plan 5,W-25A Reference: Plan: Plan 5 (W-25/Plan 5, W-25A) 14 F i t i 2="°' 1NTEQ WELL DETAILS: W-25 0.00 0.00 5959272.99 611789.00 70 1T 51.680 N 149 5' 40.953 W From Colour To MD i illi I! iiiii El El :32iii 11:!'i 11 illil 6 10986.67 87.39 158.81 8940 05 1694.13 -3946.18 20.00 270 00 1592 45 7 11274.10 55.55 107 37 9036.00 1509.14 -3766 21 20.00 230 00 1595 98 3' ° - ::- -1-I 176:: ' C s 0 7- . 166- - = / -_ ,.. ..0 11_ „..... .... - 144 ........„...',..,,.. • _ _ 112 __ _ 34, : 96 - Ilw 7 :64°1:: \‘‘\\\\\\\\\\\‘‘‘6\ SURVEY PROGRAM Date: 2009-04-30700:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool filli iikkik// i - 48 :: \\‘\\\ 11\\11\*1111 50.60 10095.54 1 : Schlumberger GCT multishoGOM-111, 10095.54 11274.10 Plan 5 (Plan 5, W-25A) MWD 2 7 , ilit I # - ' 4 ;? 2: i \ \ I I I I I 1 \ 1 1 1 11 1 t4 ' 9 0 i li: i i L . 6111$S\ iiiiiiiiii /////iiiiii : - 46 :- 1 _ / /////// -.,..........,,,,,, A.- YAW WINWISAY12 /////////// A 141.....1 YABALIVA . _ 80 ..`,,_■,' .'-'''''':-'*".';',........... _ _ , '..."''''..„.„,....„..........:'-...'°'-'''''°-...''''''-, 180 -0- YAP WW1 WAOY2 Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [16 ft/in] Vegas • • BAKER HUGHES malogiv INTEQ North America - ALASKA - BP Prudhoe Bay PB W Pad W -25 Plan 5, W -25A Plan 5 Travelling Cylinder Report 30 April, 2009 � bp • s • BP Exploration Alaska S by Travelling Cylinder Report INTEQ Company North America - ALASKA - BP Lo Cordinate IReferent a Well W -25 Project Prudhoe Bay TY Reference: : W -25 @ 91.00ft (generic drilling rig) Refere Sites PI3 W Pad MD:,Refetaence:..�- . W -25 © 91.00ft (generic drilling rig) Site Error i 0.00ft North Reference True Reference Wei( W -25 Survey Calculation Method Minimum Curvature WeD Error ° 0.00ft output errors are at 1.00 sigma Reference Weiibore Plan 5, W -25A "Databas EDM .16 - Anc Prod - WH24P Reference Design r Plan 5 ; offset TVD Reference: `• Offset Datum Reference, ,. Plan 5' Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 10,095.54 to 11,274.1 Oft Scan Method: Tray. Cylinder North Results Limited by: Maximum center - center distance of 1,323.63ft Error Surface: Elliptical Conic Survey Tool Program Date 4/30/2009 Prom o ,:. ) : ( T} , ? Survey (Wfelibore) Tool Name Descnptton { ft ..eft 50.60 10,095.54 1 : Schlumberger GCT multishot (W -25) GCT -MS Schlumberger GCT multishot 10,095.54 11,274.10 Plan 5 (Plan 5, W -25A) MWD MWD - Standard Caaitg Pois Measured V er ti cal Casing Hole Depth Depth Diameter . ' Diam t (#t) (R) Name (ln) In) 11,274.10 9,036.00 2 3/8" 2.375 3.000 2,676.00 2,675.96 13 3/8" 13.375 17.500 10,085.00 8,743.97 9 5/8" 9.625 12.250 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 4/30/2009 3:20:50PM Page 2 of 9 COMPASS 2003.16 Build 70 BP Exploration Alaska • by Travelling Cylinder Report 0 1NTEQ on pant' North America - ALASKA - BP Local,Co- o rdinate R ef e r e lnc+ W W -25 Project ' Prudhoe Bay TVD ncg; W -25 @ 91.00ft (generic drilling rig) Reference Site; PB W Pad <MD Reference: W -25 @ 91.00ft (generic drilling rig) .:,.,,',,: Site "Error,, . O.00ft North.Refer'ence True Reference Well W -25 Survey Calculation Method , ° Minimum Curvature Welt:Error O.00ft Output errors are at . 1.00 sigma Reference Wellhore Plan 5, W -25A Database:. , _ : EOM .16 - Anc Prod - WH24P Reference Desin g Plan 5 Offset T VD References ' Offset Datum Summary .. Reference; . offset Centre: to , No-Go AAllowabie Measured Mea sur Centre Distance ; Oeviatlofr Warnitng Site Nam I pth Depth Distancte ( ,ro Pla , t ffsset Well Wetibore Design (ft) (ft} ER) t ) PB W Pad Plan W -49 (32 -33) - Plan W-49 - Plan #1 W-49 Out of range Plan W -59 - Plan W -59 - Plan #1 W -59 10,150.00 10,475.00 1,134.09 186.80 949.11 Pass - Major Risk W -02 - W-02A - Plan #13 Out of range W -02 - W -02A - W -02A Out of range W -19 - Plan W -19B - Plan #13 W -19B Out of range W -19 - Plan W -19BL1 - Plan #11 W -19BL1 Out of range W -19 - Plan W-19BL1PB1 - Plan #4 W-19BL1PB1 Out of range W -19 - W -19 - W -19 Out of range W -19 - W -19A - W -19A Out of range W -19 - W -19AL1 - Plan #11 Out of range W -19 - W -19AL1 - W -19AL1 Out of range W -19 - W -19AL1 PB1 - W-1 9AL1 PB1 Out of range W -19 - W -19AL1 PB2 - W-1 9AL1 PB2 Out of range W -25 - W -25 - W -25 10,124.83 10,125.00 2.00 2.53 -0.53 FAIL - Major Risk W -26 - W -26 - W -26 Out of range W -26 - W -26A - W -26A Out of range W -27 - Plan W -27B - Plan #1 Out of range W -27 - W -27 - W -27 Out of range W -27 - W -27A - Plan #3 Out of range W -27 - W -27A - W -27A Out of range W -29 - W -29 - W -29 Out of range W -31 - W -31 - W -31 Out of range W -31 - W -31A - W -31A 10,950.00 10,875.00 1,046.57 485.06 566.46 Pass - Major Risk W -32 - W -32 - W -32 Out of range W -34 - W -34 - W -34 11,225.00 10,675.00 1,317.27 799.21 533.17 Pass - Major Risk W -34 - W -34A - Plan #4 Out of range W -34 - W -34A - W -34A Out of range W -34 - W- 34APB1 - W- 34APB1 Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 4/30/2009 3:20:50PM Page 3 of 9 COMPASS 2003.16 Build 70 Alaska Department of Naturalesources Land Administration System. Page 1 of/ Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28263 8 Printable Case File Summary See Township, Range, Section and Acreage? New Search ) Yes (iNo LAS Menu 1 Case Abstract 1 Case Detail 1 Land Abstract p File: ADL 28263 Search for Status Plat Updates As of 09/22/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/11/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 05/04/2009 Case Subtype: NS NORTH SLOPE Last Transaction: CHNGTEXT CHANGE LEGAL TEXT Meridian: U Township: O11N Range: 012E Section: 15 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 012E Section: 16 Section Acres: 640 Meridian: U Township: O11N Range: 012E Section: 21 Section Acres: 640 Meridian: U Township: 011N Range: 012E Section: 22 Section Acres: 640 Legal Description 05 -28 -1965 * ** SALE NOTICE LEGAL DESCRIPTION * ** C14 -59 T11N, R12E, UM 15, 16, 21, 22 2560.00 11 -28 -1969 SEGMENT 1 T11N,R12E,UM SECTION 15: 640 ACRES SECTION 16: 640 ACRES http: / /dnr.alaska.gov /projects /las /Case Summary.cfm ?FileType= ADL &FileNumber = 2826... 9/22/2009 • Ramirez, Darlene V (DOA) From: Seamount, Dan T (DOA) Sent: Monday, September 28, 2009 9:27 AM To: Ramirez, Darlene V (DOA) Subject: Re: 209 -102f Approved Sent from my iPhone On Sep 25, 2009, at 4:03 PM, "Ramirez, Darlene V (DOA)" <darlene.ramirez @alaska.gov > wrote: > «S45C- 209092513460.pdf» > The message is ready to be sent with the following file or link > attachments: > S45C- 209092513460.pdf > Note: To protect against computer viruses, e-mail programs may > prevent sending or receiving certain types of file attachments. > Check your e-mail security settings to determine how attachments are > handled. > <S45C- 209092513460.pdf> 1 i • TRANSMITTAL LETTER CHECKLIST WELL NAME - 7S&/ !/v - c ' 4 PTD# c=VO 9 /0,7g ✓ Development Service Exploratory Stratigraphic Test Non- Conventional Well FIELD: �,P,u ,v40.e X 4Y POOL: ,'64'd " .04V C9/4 Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 ... . ., n„ ,. w gi p, s Field & Pool PRUDHOE BAY, PRUDHOE OIL _640150 Well Name: PRUDHOE BAY UNIT W -25A Program DEV Well bore seg ❑ PTD #:2091020 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV / PEND GeoArea 890 _ Unit 11650 On /Off Shore On _ Annular Disposal ❑ Administration 1 Permit fee attached NA 1 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes Prudhoe Bay Oil 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 2560 acres. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force No Blanket Bond #6194193. 111 Permit can be issued without conservation order Yes A pp r Date l '12 Permit can be issued without administrative approval Yes ACS 9/22/2009 ' Can permit be approved before 15 -day wait Yes 1 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(1.1.A),(j.2.A -D) NA 18 Conductor string provided NA Conductor set in W -25 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in W -25 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented . 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in W -25 1 22 CMT will cover all known productive horizons Yes 2 3/8 " liner will be cemented back inside window 23 Casing designs adequate for C, T, B & permafrost Yes 124 Adequate tankage or reserve pit Yes Rig equipped with Steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved Yes 309 -341 P & A sundry 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Passes all risk criteria. 27 If diverter required, does it meet regulations NA Wellhead already in place. BOP stack on top of tree. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes KWF = 7,9 ppg Drilling with 8.6 ppg mud GLS 9/24/2009 129 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP = 2720 psi ... Testing BOP's to 3500 psi III 31 Choke manifold complies w /API RP -53 (May 84) Yes 132 Work will occur without operation shutdown Yes 1 Is presence of H2S gas probable Yes H2S on pad. Rig has alarms and sensors. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Max level H2S on W pad was 56ppm. Geology 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 9/22/2009 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] Yes Ron Phillips - 564 -5913 Geologic Engineering Public J ` � Comm' l oner: Aat : Commissioner: Date Commissioner Date :M 2 W2F-69? • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically • organize this category of information. w i tapescan.txt * * ** REEL HEADER * * ** MWD 10/02/10 BHI 01 LIS Customer Format Tape * * ** TAPE HEADER * * ** MWD 09/12/05 2902041 01 2.375" CTK * ** LIS COMMENT RECORD * ** 111111 Remark File Version 1.000 1111111111111111111 Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard - VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 9833.0000: Starting Depth STOP.FT 11240.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. - 999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: W -25A FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 70 deg 17' 51.680 "N 149 deg 5' 40.953 "W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 05 Dec 2009 API . API NUMBER: 500292187401 -Parameter Information Block #MNEM.UNIT Value Description SECT. 21 Section TOWN.N T11N Township RANG. R12E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . DF Log Measured from FAPD.F 91.00 Feet Above Perm. Datum DMF . DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 91.00 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 Qp - 10 1`)cia5 4 r tapescan.txt CASE.F N/A Casing Depth 051 DIRECTIONAL Other Services Line 1 -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (TVDSS) are subsea corrected. All True vertical Depths 55 a (3) C ) (4) 4 All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and any depth adjusting has been waived. The MWD data is the Primary Depth Control (PDC) log for well W -25A per Kurt Cooney with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from w -25 through a milled window in a 7 inch liner. Top of window 10100 ft.MD (8665.1 ft.TVDSS) Bottom of window 10105 ft.MD (8669.1 ft.TVDSS) (9) Tied to w -25 at 10095 feet MD (8661.5 feet TVDSS). (10) The interval from 11215 ft to 11240 ft MD (8909.0 ft. to 8922.0 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD -API units) ROP AVG -> Rate of Penetration, feet /hour RACLX -> Resistivity (AT)(LS)400kHz- Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz- Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz- Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz- Compensated Borehole Corrected (OHMM) TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 74 records... Minimum record length: 10 bytes Maximum record length: 132 bytes * * ** FILE HEADER * * ** MWD .001 1024 * ** INFORMATION TABLE: CONS * ** LIS COMMENT RECORD * ** Page 2 • . tapescan.txt Remark File version 1.000 The data presented here is final and any depth adjusting has been waived. The MWD data is the Primary Depth control (PDC) log for well w - 25A per Kurt Cooney with BP Exploration (Alaska), Inc. * ** INFORMATION TABLE: CIFO * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub -type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code samples units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 79 Tape File Start Depth = 9833.000000 Tape File End Depth = 11240.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet * * ** FILE TRAILER * * ** Tape Subfile: 2 92 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** FILE HEADER * * ** MWD .002 Page 3 tapescan.txt 1024 * ** INFORMATION TABLE: CONS * ** LIS COMMENT RECORD * ** 1111111111111111111 Remark File version 1.000 This file contains the raw - unedited field MWD data. * ** INFORMATION TABLE: CIFO * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block Sub -type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 157 Tape File start Depth = 9832.750000 Tape File End Depth = 11240.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet * * ** FILE TRAILER * * ** Tape Subfile: 3 170 records... Page 4 • • tapescan.txt Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** TAPE TRAILER * * ** MWD 09/12/05 2902041 01 * * ** REEL TRAILER * * ** MWD 10/02/10 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape subfile 1 is type: LIS 0 Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9833.0000 50.7000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 9833.5000 53.1000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 11240.0000 - 999.2500 174.8000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 9833.000000 Tape File End Depth = 11240.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS Page 5 • 1 tapescan.txt RPD RPS 9832.7500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 9833.0000 50.7000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 11240.0000 - 999.2500 174.8000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File start Depth = 9832.750000 Tape File End Depth = 11240.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet 0 Tape subfile 4 is type: LIS Page 6
