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208-174
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, May 5, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC W-218 PRUDHOE BAY UN POL W-218 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/05/2025 W-218 50-029-23403-00-00 208-174-0 G SPT 5005 2081740 1500 1141 1145 1140 1136 50 60 62 61 4YRTST P Guy Cook 4/8/2025 Testing completed with calibrated gauges and a Little Red Services pump truck. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL W-218 Inspection Date: Tubing OA Packer Depth 8 1792 1728 1714IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250408065729 BBL Pumped:4.6 BBL Returned:2 Monday, May 5, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.05 09:06:18 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg/ DATE: Monday, April 26, 2021 P.I. Supervisor �aa. [ 5I/ i1(� SUBJECT: Mechanical Integrity Tests Hdcorp North Slope, LUC W-218 FROM: Austin McLeod PRUDHOE BAY UN POL W-218 Petroleum Inspector Src: Inspector Reviewed By: P.I. supry J NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POE W-218 API Well Number 50-029-23403-00-00 Inspector Name: Austin McLeod InSp Num: mitSAM210415I64520 Permit Number: 208-174-0 Inspection Date: 4/13/2021 Rel Insp Num: Packer Depth Well I W-218 Type Inj W ITVD 1 5005 PTD zos174o Type Test SPT Test psi 1500 BBL Pumped: 2 - BBL Returned: L7 Interval 4YRTST Notes: MIT -IA Pretest Initial 15 Min 30 Min 45 Min 60 Min ubing 872 862 F 871 - 873 IA 42 1702. 1646 - 1636 OA 198 433 _ 429 - 423 Monday, April 26, 2021 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,April 14,2017 P.I.PSupervisorSUBJECT: Mechanical Integrity Tests \\O%\%\\_\ BPEXPLORATION(ALASKA)INC. W-218 FROM: Brian Bixby PRUDHOE BAY UN POL W-218 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Valk NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL W-218 API Well Number 50-029-23403-00-00 Inspector Name: Brian Bixby Permit Number: 208-174-0 Inspection Date: 4/12/2017 Insp Num: mitBDB170412145603 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ' W-218 Type Inj I w TVD 5005 Tubing 590 590 592 593 PTD 2081740 Type Test SPT Test psi 1500 IA 31 1683 1638 1632 BBL Pumped: 1.8 BBL Returned: 1.9 OA 190 291 293 292 Interval 4YRTST P/F P Notes: 17 INKED A11 G 1 5 2:D Friday,April 14,2017 Page 1 of 1 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ~ WAG SWAP Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter.Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development ^ Exploratory ^ 208-1740 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ API Number: Anchorage, AK 99519-6612 50-029-23403-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number ADLO-028263 ~ "'~ r~ . PBU W-218 10. Field/Pool(s): PRUDHOE BAY FIELD /POLARIS POOL 11. Present Well Condition Summary: Total Depth measured 10080 feet Plugs (measured) None feet true vertical 5366.69 feet Junk (measured) None feet Effective Depth measured 9985 feet Packer (measured) 9377 9535 9700 true vertical 5316.63 feet (true vertical) 5005 5081 5167 Casing Length Size MD TVD Burst Collapse Structural Conductor 108 20" 91.5# A-53 SURFACE - 108 SURFACE - 108 Surface 5461 9-5/8"47# L-80 29 -5461 29 - 3419 6870 4760 Intermediate Production 10071 7" 26# L-80 26 - 10071 26 - 5362 7240 5410 Liner Liner Perforation depth: Measured depth: O 9429 - 9474 O 9600 - 9644 O 9704 - 9779 True Vertical depth: 5029.96 - 5051.65 5113.91 - 5136.89 5168.78 - 5208.53 = _ Tubing: (size, grade, measured and true vertical depth) 3-1/2" 9.2# L-80 SURFACE - 9902 SURFACE - 5273 " " K Packers and SSSV (type, measured and true vertical depth) 7 X 3-1/2 HES DUAL FEED THRU PKR 9377 ~ 5005 7" X 3-1/2" HES DUAL FEED THRU PKR 9535 5081 7" X 3-1/2" HES DUAL FEED THRU PKR 9700 5167 12. Stimulation or cement squeeze summary: ~~ ~~ . ~ ~~, Intervals treated (measured): S-'~d~Y~~Sr4 ~~ ~,~ ~; ~, <x ~ ~ ~ - e q (~ r„~ ~O I~.I Treatment descriptions including volumes used and final pressure: Qj` „ y ~ j ~ 13. Representative Daily Average Production or Injection Data .,,,:: ,sr,<~ Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 681 1439 Subsequent to operation: 2219 2485 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Q Daily Report of Well Operations X Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^~ GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N!A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 7/7/2010 i vnn iu-+v ~~cviacu n~u~~D~~ ~~ ~ ~ ~ v-I R II alai vrny ~z 3 -! a ~ r/M/1y • 1 W-218 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/14/20101***WELL INJECTING ON ARRIVAL"*" RU SWCP #10, STANDBY FOR LRS 'PUMP TRUCK UNAVAILABLE, JOB POSTPONED **"LEFT WELL INJECTING, INFORM PAD OP*** 6/2010''""WELL INJECTING ON ARRIVAL***(pre swap to MI) ;LRS FREEZE PROTECT FLOWLINE 1PUMPED 58 BBLS DIESEL TO DISPLACE WELL AS PER PROGRAM SET 3 1/2" WHIDDON C-SUB @ 6744' SLM PERFORM INJECTIVITY TEST AS PER PROGRAM (GOOD) 1PULLED RK-WFR FROM ST#1 @ 6706'SLM/6728'M IB&F W/ LRS, PUMPED 70 BBLS AWAY, USING 3-1/2" BLB, 2.50"G-RING TO ? 6720 SLM (no issues) OOH W/BRUSH, R/D FOR WEATHER (high winds 40+) ***CONT WSR ON 5-17-10**'` 5/16/2010 T/I/O 1100/20/240 Assist slick-line with WFR redesign (Prep for WAG swap) Freeze protect FL and S-riser. Pumped 6 bbls neat methanol down FL and into S- riser to freeze protect. Pumped 2 bbls neat, followed by 58 bbls of 30* dsl down `TBG to displace water. TP fell to 1600 psi after shutting down pump. SSL to RIH and set catcher. Perform SRT. Pumped a total 8.3 bbls during infectivity test. Pump rates and pressure .10 bpm. @ 1300 psi. for 5 mins .32 bpm. @ 1500 psi. for 5 mins .58 bpm. @ 1700 psi. for 5 mins. SSL pulled WFR from GLM#1. Pumped 70 bbls 180* diesel during brush and flush. i***Continue AWGRS on 5/17/10*** 5/17/2010[***Continued AWGRS from 05-16-10**" Job postponed due to high winds • 5/18/2010 5/18/2010 ~~ ~_____W__ _~~_ ____________ T/I/0= 300/20/180 Temp= SI Assist wireline pump as directed- Pumped 16 bbls diesel down tubing through WFR in sta. #1 to capture rates at .20 bpm @ 1300 psi, .45 bpm @ 1500 psi and .76 bpm @ 1700 psi each for 5 min test without change. Turn well over to SSL. Final W HP's= 1000/20/180 "Slickline has control of well at departure" """CONY WSR FROM 5-16-10*"*(pre-swap to MI) SET RK- P-15 WFR IN STA #1 @ 6706' SLM/ 6728' MD PULL C-SUB FROM 6740' SLM PERFORM INJECTIVITY TEST AS PER PROGRAM, GOOD TEST SET 3 1/2" MCX (SER-# BP-327) W/.50" BEAN IN SVLN @ 2786' SLM/ 2809' MD PERFORMED GOOD DRAW DOWN TEST ON INJ VALVE, RDMO "**WELL LEFT S/I, TURNED OVER TO PAD OP TO POI/ GAS*** FLUIDS PUMPED BBLS 7 MEOH 100 diesel 107 Total TREE = CNV WELLHEAD = FMC ACTUATOR = BAKER KB. ELEV = 81.7' BF. ELEV = 55.68' KOP = 300' Max Angle = 70° @ 7969' Datum MD = 9536' Datum TV D = 5000' SS ~ W-218 (20" CONDUCTOR, 94#, A-55, ID = 19.124" ~ 108' 9-5/8" CSG, 47#, L-80 BTC, ID = 8.681" 5461 7" CSG, 28#, L-80 TCII XO TO L-80 BTGM --C Minimum ID = 2.750" @ 9880' 3-1/2"HES XN NIPPLE 7" MARKER JOINT w / RA TAGI~, 7" X 3-112" HES DUEL FEED THRU I 93TT' PKR, ID = 2.965" 3-1/2"MARKER JOINTw/ RA TAG 9434' PERFORATION SUMMARY REF LOG: SLB USIT ON 12/11/08 ANGLE AT TOP PERF: NiA Note: Refer to Production DB for historical perf data SIZE SPF ZONE INTERVAL Opn/Sqz DATE 4-112" 5 OBa 9429 - 9474 O 12110/08 4-112" 5 OBc 9600 - 9644 O 12/10108 4-1/2" 5 OBd 9704 - 9779 O 12/10!08 3-1/2" HES X NIP, ID = 2.813" GAS LIFT MANDRELS DEV TYPE _VLV LATCH 61 MMG DMY RK WATER INJECTION MANDREL S ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 9415 5023 61 MMG-W DMY RK 0 04/11 /09 4 9505 5067 61 MMG-W P-15 RK 12 04/11/09 3 9623 5126 59 MMG-W DMY RK 0 04111(09 2 9671 5151 58 MMG-W P-15 RK 12 04/11/09 1 9821 5230 5$ MMG-W P-15 RK 18 05/18/10 9346' 3-1 /2" HES X NIP, ID = 2.813 3-112" NDPG PRESSURE GAUGE, ID = 2.992" 9535, I-{ 7" X 3-1 /2" HES DUEL FEED THRU I PKR, ID = 2.965" 9548 3-1/2" NDPG PRESSURE GAUGE, ID = 2.992" 9593 3-1 /2" HES X NIP, ID = 2.813' 9700 ~ 7" X 3-1/2" HES DUEL FEED THRU I PKR, ID = 2.965" 9713' 3-1/2" NDPG PRESSURE GAUGE, ID = 2.992" 9800 3-1 /2" HES X NIP, ID = 2.813" 3-1 /2" HES X NIP, ID = 2.813" 9880 i--i 3-1/2" HES XN NIP, ID = 2.750" 3-1 /2" TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" ( 9902' PBTD 9985' 7" CSG, 26#, L-80 BTGM .0383 bpf, ID = 6.276" 10070 9902' ~-{ 3-112" WLEG, ID = 2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS 12114!08 N9ES ORIGINAL COMPLETION 02!25109 ?/ PJC DRLG DRAFT CORRECTIONS 03!09109 TW/PJC DRLG DRAFT CORRECTIONS 05/31/09 DAV/TLH GLV GO (04/11/09) 05/30/10 BSFJPJC GLV C/O (05/18!10) POLARIS UNIT WELL: W-218 PERM(f No: 2081740 API No: 50-029-23403-00 SEC 21, T11 N, R11 E, 316' FNL 8~ 1745' FEL BP Exploration (Alaska) ~J • ~l~Q~~ 00 ~ Q~Q~~{Q /,E,.Po,~..ao~.~ GPB West Subsurface Resource Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~ ,~ ~;t.::~~, (, i~± rl ~ ~~~~~~ Re: Request to Allow Enriched Hydrocarbon Gas Injection PBU W-218 (PTD 2081740) Polaris Oil Pool Dear Ms. Richmond: By letter dated March 29, 2010, BP Exploration (Alaska) Inc. (BPXA) requested approval to allow enriched hydrocarbon gas injection in Well PBU Polaris W-218 (PTD 2081740)). The Commission GRANTS BPXA's request in accordance with Rules 2 and 13 of AIO 25A.000. An Application for Sundry Approval (Form 10-403) is not required; however a Report of Sundry Well Operations (Form 10-404) should be submitted documenting the commencement of enriched gas injection. DONE at Anchorage, Alaska and dated Apri126, 2010. Conservation Commission f 1 aniel T. amount, Jr. o Orman. Cathy . Foerster Commissioner, Chair mmi er Comm ssioner • • AIO 25A.007 Apri126, 2010 Page 2 of 2 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(6), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday b ~ ~ p March 29, 2010 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 Darnel T. SeamOUnt (907) 561-5111 ~~~ ®~ Chairman ~~'Sy Alaska Oil and Gas Conservation Commission 333 West 7t1i Avenue, Suite 100 BAR ~ ~ ZQ~Q Anchorage, AK 99501 0~ ~ C~ Cons. C,anmissi~n RE: Administrative Approval for Enriched Hydrocarbon Gas Injection in Well PBU W-218 ~' Dear Chairman Seamount: BP Exploration (Alaska), Inc. (BPXA), operator of the Prudhoe Bay Unit (PBU), on behalf of itself and the other the PBU Working Interest Owners, requests administrative approval under Area Injection Order No. 25A (AIO 25A) to allow for the injection of enriched hydrocarbon gas into injection well W-218. ~~~. _ ~~ ~\ The following wells are approved for enriched hydrocarbon gas injection under AIO 25A Rule 2: 5-215i, W-209i, and W-215i. The rule also states that upon "proper application" additional water injecting wells can be reclassified as WAG injectors. W-218i was drilled in December 2008 and is currently approved for water injection. Figure 1 provides data on the zonal isolation status of the wellbore. There are no offset injectors present within aone-quarter mile radius of W-218i as depicted by Figure 2. One offset Polaris producer, W-204, is located 1300 feet from W-218i. The top of cement (TOC) in W-218i was determined by a cement bond log to be 5068' MD, providing 3722' MD of coverage above the top of the pool. BPXA believes that injected fluids will be confined within the appropriate receiving intervals. Should you have any questions regarding this request, please contact Maggie Orlando at 564 - 4741. Thank you for timely consideration of this request. Sincerely, ~, n~ Diane Richmond GPB WEST, Resource Manager CC: Mark Agnew (ExxonMobil) Dan Kruse (CPAI) Glenn Frederick (Chevron) Alan Mitchell (BPXA) David Lenig (BPXA) Claire Sullivan. (BPXA) Attachments: Figure 1: Zonal Isolation Status of Wellbores within One-Quarter Mile of W-218i Figure 2: W-218i'/ mi Radius Map • • March 18, 2010 Page 2 Figure 1: "Zonal Isolation Status of Wellbore: Well Dist from TOC, TOC Determination injector, ft 117(D Method W-218i 0 5068 Cement Bond Log Dated 11 /Dec/2008 W-204 1300 NA NA Within One-Quarter Mile of W-218i Top Pool (MC Top Injection Coverage sand), MD Sand (Oba), MD 8790 9419 3722' MD NA NA Offset producer 2: W-2181 '/a mi Radius 5,968,000 5,966,000 m 5,964,000 5,962,000 .a ~ ~~ m 5,960,000 --.~' a87° X879 - -:a• w-S~. b0 w- r- 79 610,000 612,000 614,000 616,000 Schrader Bluff OBa Depth Structure Map 20' Contour Interval. '/< mile circle around SB_OBa injection zone for W-214, W-216, W-217, W-218 • • ~~ `~~ ~~C7 C~~. ~NZEC~i~ ~®Rr . ~` MUD v- == ~ = >>~-~~ C~ER ~ FIELD \~ ~ ~ ~ ~o `c~r-~ ~ _ ~ .. ER `_ ~F~ T.L DF T 4 '~~ : 100~C~.k~.. 53 6 'I'v'D. ~ ®E~A : ~. ~S ?31~~~ a C ~; a,r ~ : ~~ S~~o ~ : Op'1 t°iD 53 ~ i ~ll ~ u'V . N .~~, ~~,~ .. u Z'o \` , ol~ Si~~ _.~~~?~.~ 2.x~c~ ~t~ ~; Ferns ~ ~ to .,~,. ~., ~ . ~nnu a, u, ~ ~ r ~ s ~ ~: ~ ~ ~ : _..~.,_...~-~4 i ~. ~ t~~xa - ~ r 0 Bai.r~._...~..~.4~„ Co~on~s : ~(1~ 4~ ~~~ ~~~ Cesacn~ V®:t.u~~;~:. ~.~~~ i~~es N~. G~~~6~ DV ~.~ C~~ soZ ~o oover caer<.s 3 ~ ~. ~s ~, ~ ~~,~t ..~ ~ - '~heo~ee~c~~ BOG '~' (p ~~~,~~~~~~~-..~c ~~- ~ ~~ .,.,.~a.~..._~.~....~,.~-,~ -.~.~-_~s.~.~..~..._._ _..___----. _. _ Q g C g Cemerbr, Eons ~-®~ (des or No)_'~~„_,_„~; ~:n l~~~CC ~ile~~.;~,,.® C9I- :.vs,J,u~~:ir~n 4 : osa~: eoove perfS ~-:~ - ~~ ~''l ~,®~s~ r Pxoauor~ion T~o~: .~.y~pe z Evs us.~ion CaHCLUS i~?N5 ~~~rz ~1; 7 n~.:: ,.__...~ __..__ /~~ l~~~~'~at,'~O Page 1 of 1 i • Maunder, Thomas E ~DC)A) From: West, Taylor [Taylor.Wes#@bp.com] Sent: Thursday, April 15, 2010 12:27 PM To: Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: AA request W-298 (208-174) Tom: sorry... I have been out, so still going through my e-mails. quick answer to your question: No temp logging done on W-218. temp logging doesn't work too well for channel detection on our wells for two reasons: 1. Minimal temp difference between injection water when it reaches the sandface and the formation temp (usually 2. our completion uses tubing straddled zones, so the formation is behind two sets of pipe, and therefore any temp signature is muted by the "thermos bottle" effect. Despite the relatively poor cement quality in W-218 as compared to our other injectors, I am confident that we have sufficient isolation to do MI operations safely. Thx Taylor From; Maur-der, Thomas E {DOA) [rr~tto:tom.maurx~r@ataska.gov] Seat: Monday, April 12, 2010 4:01 PM To; Orlando, Margaret Cc: West, Taylor Subject: AA request W-218 (208-174 Maggie, I am finishing up with the AA requests sent in for M! injection in 5 Polaris wells. I've completed al! but the request for W-218. In looking a# ~e file, Taylor and I exchanged some messages in early 2009 discussing the pessimis#ic US1T log.. Water injection was approved. ! am curious if BP has any obtained any temperature k~ information since the wail has been injecting? Thanks in advance, Tom Maunder, PE AOGCC 4/16/2010 Page 1 of 2 AAaunder, Thomas E {DOA, From: West, Taylor [Taylor.West~bp.com~ Sent: Thursday, April 15, 2010 14:35 AM To; Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: Margare#.Oriando@bp.com Subject: FW: W-218 (208-174) Tom / Guy: I just got back today from an exciting at-sea adventure with my son -- I'll have to fill you in. below is a copy of our earlier discussion regarding W-218 cement job to supplement the request for MI injection approval. if you guys are available, maybe we can discuss this by phone? Maggie and I are pretty flexible for time. thx Taylor West Production Engineer Orion /Polaris Viscous Oil BP Exploration {Alaska), Inc. 907.564.4647 (desk) 907.632.0111 (cell) 907.564.5016 (fax) From: West, Taylor Sen#: Tuesday, February 03, 2009 5:10 PM To: 'Maunder, Thomas E (DOA)' Cc: Sullivan, Claire; Trpadc, Rout 6 ~,b?ect: ~E: w-2~s X20$-i~~> Tom: As requested, below is an analysis of the W-218 cement job: Problem_ Cement quality across the 7" casing interval is uncharacteristically poor fln new injector W- 218drilled in December 24fl8. Root Cause Analysis-: Casing reciprocation was stopped after the mud push was pumped past the stifle, but before cement was pumped into the annulus. This was done due to reduced casing slack-off weight. The drilling and asset team believe that the probable cause of poor cement distribution is the lack of pipe reciprocation while cement was being lifted across the O-sands. Low Analysis ! Utility: 4I1~12010 Page 2 of 2 The USIT log reveals patchy law-side channeling across the entire logged interval. Good isolation areas exist throughout the interval in 10-40' sections interspersed between channels. Water and MI injection should. be contained in the injection zone by good quality cement isolation in intervals: $060-8120' md, $222-8260', 9034-9040', 9330-9400' md. There are numerous sections with "adequate" isolation, 10'+ in length, -most likely adequate to prevent annular flow. Within the injection zones, good isolation exists that should prevent cross flow between 0-sands: 9496-9542' md, 9656-9680' md. Remediation Analysis:. Based on prior logging analysis experience and squeeze experience, it is unlikely that the channeling can be successfully squeezed. The random cement patches and disconnected channels would make a circulation squeeze or a block squeeze very challenging, and unlikely to succeed. at providing additional isolation. hopefully, this explanation and our phone call will address your concerns.. Thx Taylor West Production Engineer Orion /Polaris Heavy Oil BP Exploration (Alaska), Inc. 907.564.4647 (desk) 907.632.0111 (cell) 907.564.5016 (fax) From. Maunder, Thomas E {DOA) [rnailto:tom.maunder@alaska.grnr] Sent: Monday, February 02, 2009 4:34 PM To: West, Taylor Subject: W-218 (208-174) Taylor, Is this near injector one of ~yours~? Havre yon ed at the USIT (11/1/2000)? If this is not your v~rell¢ l~ rrf this erpe a to site ~raety_ I"~ a an assessrr~ent of the t1SIT a Carl or a eery 9a " ns_ Tom 141at~nderG PE AOGCC 4/16/20 i 0 DATA SUBMITTAL COMPLIANCE REPORT 3/31 /2010 Permit to Drill 2081740 Well Name/No. PRUDHOE BAY UN POL W-218 Operator BP EXPLORATION {ALASKIy INC API No. 50-029-23403-00-00 MD 10080 TVD 5367 Completion Date 12/14/2008 Completion Status 1WINJ Current Status 1WINJ UIC Y -~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: MWD GR, MWD GR / RES / NEU / AZI DEN / PWD, USIT Well Log Information: Log/ Electr Data Digital Dataset Log Log Run (data taken from Logs Portion of Master Well Data Maint Interval OH / 1 e meairrm[ rvumoer Name acme wiewa No scan: atop ~.n rcecenrea ~.vmmenrs ED D Asc Directional Survey 0 10080 Open 12/17/2008 pt Directional Survey 0 10080 Open 12/17/2008 C Asc Directional Survey 0 646 Open 12/22/2008 p Directional Survey 0 646 Open 12/22/2008 Log Sonic 5 Col 0 9940 Case 1/16/2009 USIT, GPIT, CG, CCL, Dens, Temp **LARGE LOG""" 11-Dec-2008 ~ ~-- C Pds ~~~ 17476 YSonic 0 9940 Case 1/16/2009 USIT, GPIT, CG, CCL, Dens, Temp 11-Dec-2008 C Lis ~~~ 17643 r'Sonic 1 9936 Case 3/2/2009 LIS Veri, USIT, CCL og So~aic 5 Col 0 9940 Case 3/2/2009 USIT 11-Dec-2008 ~ C Lis 18078 Induction/Resistivity 47 10072 Open 3/13/2009 LIS Veri, GR, ROP, FET, RPS, RPM, RPD, RAM, NPHI, TRPM og Induction/Resistivity 25 Blu 108 10044 Open 3/13/2009 MD Vision Service o Ind ction/Resistivity 25 Blu 108 10044 Open 3/13/2009 TVD Vision Service D C Lis ~ 17729 "Induction/Resistivity 47 10072 Open 3/20/2009 LIS Veri, GR, ROP, FET, RPS, RPM, RPD, RAM, NPHI, TRPM** COPY** tLog Induction/Resistivity 25 Blu 108 10044 Open 3/20/2009 MD Vision Service COPY I`Log Induction/Resistivity 25 Blu 108 10044 Open 3/20/2009 TVD Vision Service COPY • DATA SUBMITTAL COMPLIANCE REPORT 3131 /2010 Permit to Drill 2081740 Well Name/No. PRUDHOE BAY UN POL W-218 Operator BP EXPLORATION (ALASt(A) INC MD 10080 TVD 5367 Completion Date 12/14/2008 Completion Status 1WINJ Current Status 1WINJ Well CoreslSamples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORM TION Well Cored? A 1'd N ) Chips Received? Yom/ .~ Analysis Y.f-td-^ Received? Comments: Compliance Reviewed By: Daily History Received? ® N Formation Tops ~N Date: API No. 50-029-23403-00-00 UIC Y r MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday, May 04, 2009 Jim Regg ~~~~ 5~8~Zw P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W-218 FROM: Chuck Scheve PRUDHOE BAY UN POL W-218 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: PRUDHOE BAY UN POL W-218 Insp Num: mitCS090426063041 Rel Insp Num: API Well Number: 50-029-23403-00-00 Permit Number: 208-174-0 ~ Inspector Name: Chuck Scheve Inspection Date: 4/25/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~'-218 Type Inj. W TVD 4970 IA 1660 4000 ,. 3940 3920 - P.T.D 2os17ao TypeTest SPT Test psi lsoo OA 17o s3o szo szo Interval I~T~- P/F P ~ Tubing 1ss0 lsso 1s50 1ss0 Notes: Monday, May 04, 2009 Page 1 of 1 Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, April 20, 2009 12:01 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU W-218 / PTD 208-174 Hi Art, Please reference the following well: Well Name: PBU W-218 Permit #: 208-174 API #: 50-029-23403-00-00 Top Perf MD: 9435' Bottom Perf MD: 9785' This well began Injection on April 17, 2009 Method of Operations is: Produced Water Injection Date of Test: No Test Data for Injectors 03/18/09 ~ t,~'~i ../ Pi ~, ~`~ ~~`~;~~ 1 ~® k.~,•, ~~-m. 1 °~~ ~~ ,r %, e~~ '~ ~~~~~~~ N0.5133 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 40o Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Woll .Inh It 1 nn necrri..t:nn ~ nets m r,.l... nn J-27A AY3J-00010 CBL - / 02/21/09 1 1 S-107 AWJB-26 MEM L L U 'a- 02/25/09 1 09-34A AZ4D-00005 USIT (REVISED) 02/07/09 1 1 V-210 AWJB-00025 INJECTION PROFILE ' 02/23/09 1 1 MPB-22A AXBD-00005 MEM SCMT & TEMP PROFILE _ (rj ~ 12/23/08 1 1 V-219 12103700 USIT (REVISION #2) js . C ( 11/21/08 1 1 11-18 BOCV-00006 PRODUCTION LOG ) C(- 03/02/09 1 1 B-25 AVY5-00023 USIT - / t'" /~ 03/06/09 1 1 N-18A AYKP-00013 PRODUCTION LOG ~- (~S j - 03/11/09 1 1 F-18 AVY5-00022 USIT / ~- ~%^ _ ~- 03/04/09 1 1 3-19/R-28 AZ4D-00009 LDL / - 03/06/09 1 1 V-117 BOOR-00003 MEM PRODUCTION PROFILE ~p - ( G 03/12/09 1 1 V-211 AY3J-00014 (PROF/RST WFL -' 03/16/09 1 1 V-214 AY3J-00013 IPROF/RST WFL - 03/15/09 1 1 K-068 AWJI-00017 MCNL ~ 01/28/09 1 1 L5-15 12113027 RST - /D ~ 1- ~ 12/09/08 1 1 07-18 12071915 RST 9 12/01/08 1 1 15-15C AWJI-00015 MCNL - / 01/02/09 1 1 W-218 40018337 OH MWD/LWD EDIT °12/07/08 2 1 R-41 40018496 OH MWD/LWD EDIT ./~ ( 01/04/09 2 1 H-18 11999064 RST / - t 12/03/08 1 1 q~ ~ YLtAtit AGKNUWLtUGt RtGtIPI tlY SIGNING ANU RETURNING UNE GUPY EAGR TU: BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: I~ -a l`?s 'I t^ o v Q- t~~- w a.- o -~- n wt ~ ~>21v~ 3~l !a- i ~ ~ t^_o ~ ~ r2G f Lu ~ 3 r a l 0~` - p5- Alaska Data & Consulting Services 2525 Gambell StrPt,jta,400 Anchorage, AK 9~ ~~28~38 ... ~, ' ATTN: Beth Received by: ~ NL~ e r?~l ;G ~ ~ 02/24/09 ~l~~F~~~~~8~ N0. 5109 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 MPS-43 AZCM-00001 FMI ~ 12/29/08 1 1 P2-41 AWL9-00009 SCMT - 01/01/09 1 1 MPS-43 AZCM-00001 SONIC SCANNER / 1y2g/Og 1 1 S-26 AYTU-00014 PRODUCTION PROFILE ~ ~ = `~~c~ 02/16/09 1 1 F-45A AYLF-00018 LDL ~0?J- (~(p ~/,~.~~ 02/24/09 1 1 4-04/T-26 12083416 MEM LDL - 02/21/09 1 1 09-34A AZ4D-00005 USIT - ~- 02/07/09 1 1 W-218 11968975 USIT (REVISED) ~- ~.1.( 12/11/08 1 1 L2-18A 11999063 RST ( 11/29/08 1 1 L2-33 11999065 RST 12/07/08 1 1 4-10A/L-28 12017518 RST 09/26/08 1 1 W-218 11968975 CH EDIT PDC GR (USIT) 1?J11/08 1 DI FACC A!`VAIMII/I CI'1f!C oe l~eior ov c~~r_wu w~n n ~ `-'-°~'° BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Stree i 00' Anchorage, AK 995 ATTN: Beth Received by: l~ 02/24/09 r'~ ~l~i~~~b~~~~r N0.5109 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 WPII .Inh !t 1 ..., ne ..~:.. MPS-43 AZCM-00001 FMI 1y49/pg v ~~~ 1 P2-41 AWL9-00009 SCMT - 01/01/09 1 1 MPS-43 AZCM-00001 SONIC SCANNER / 12/29/09 1 1 S-26 AYTU-00014 PRODUCTION PROFILE l ~ _ r~-~-(. _ 02/16/09 1 1 F-45A AYLF-00018 LDL ~03- ~~ ~/~~~ 02/24/09 1 1 4-04/T-26 12083416 MEM LDL CP 02/21/09 1 1 09-34A AZ4D-00005 USIT - ~- ~ ? 'r 02/07/09 1 1 W-218 11968975 USIT (REVISED) ~.C . ~t.( 12/11/08 1 i L2-18A 11999063 RST ( 11/29/08 1 1 L2-33 11999065 RST ~( 12/07/08 1 1 4-10A/L-28 12017518 RST - 09/26/08 1 1 W-218 11968975 CH EDIT PDC GR (USIT) iyii/OS 1 of Gecc n~irnin~nn onr_e oo ne~or nv e~n•u un n BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Stree i t)p''` Anchorage, AK 995 !~ ATTN: Beth Received by: • Page 1 of 3 Maunder, Thomas E (DOA) From: Tirpack, Robert B [Robert.Tirpack@bp.com] Sent: Monday, February 09, 2009 6:27 AM To: Maunder, Thomas E (DOA) Cc: Staudinger, Garret Subject: RE: w-218 (208-174) Attachments: W-218 cement.xls Tom, Thank you far taking such an interest in our inter-zonal isolation on W-2181. This well has received much attention due to the poar USIT log. The 8-112" hole in W-218i was drilled without any issues: na losses, no tight spots. The final trip out of the hole with the drilling BHA also showed no anomalies. The trip in the hole with the 7" casing also went without issue. Once on bottom, all of our standard operating procedures were followed. The PU and SO weights before cementing were normal. At the time the lead cement reached the shoe; the SO weight went from 90k to 50k Ibs. This 30k, 33°lfl reduction in SOW prompted the Well Site Leader to land the casing on the mandrel hanger.. This was done for two main reasons: 1 }At the time the WSL did not want to risk perforation interval by sticking the casing high. 2}The WSL did not want to risk sticking the casing at a depth that would place the mandrel hanger in the emergency slip area, thus rendering bath system useless. We do not model casing PU and SO weights as cement is pumped and displaced. With hind sight being 20120; there are actions that could have been taken that may have prolonged the casing reciprocation. l was not on the rig floor; so I can not second guess the actions of the WSL. We feel the main contributor to the poor cement job was the lack of reciprocation for the entire cement job. We have meet with-in BP and come up with some cantingencies that may allow longer reciprocation periods: 1)TD°s will be picked such that if casing is stuck aff bottom, there will be plenty of rathole above the shoetrack to still allow perforation of al9 zones of interest. 2}wells that are determined to be higher risk (hole problems, higher angle, etc), the base plan will be to use emergency slips and not pick up the mandrel hangerlrunning joint. We are also looking into the costlbenefits of casing rotating equipment to help cement placement. As far as the cement yields are concerned, please see the attached table from Garret. The surface lead varied between 4.44 and 3.96 cflsk. According to Schlumberger, these values are with-in normal ranges based an density variations of the cement and additives delivered to the slope. The production hole lead cement yield varied from 2.35 in the permit to 2.95 cftsk that was actually pumped. This is due to the fact that 12.0 ppg was shown in the permit and 11.5 ppg was actually pumped. After the permit was submitted; it was decided to drop the cement weight due to high ECD's during displacement. Also, as you noted; all volumes still met the state requirements for cement coverage. Regards, Rob Rob Tirpaok Fng Team Lead GPB Rotary Drilling 907-554-4166 office 907-440-8533 cell tirpacrb@bp.com 2/9/2009 • Page 2 of 3 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, February 03, 2009 4:49 PM To: Staudinger, Garret Cc: Tirpack, Robert B Subject: RE: w-218 (208-174) Garret, It partially provides an answer. What were the PU and SO weights? Sometimes they are listed in the summary, but not this one. Was 30K a significant weight loss? Is there any modeling done to understand how the weights change during cementing? If I remember correctly, it has been possible to move pipe out there on most wells but I do realize that every hole section is different. For this particular well, the USIT log gives a pretty pessimistic assessment of the cement quality. There is likely sufficient isolation there to keep fluids confined to the Schrader, however isolation between the specific sands is another issue. I also have a comment regarding "slips" and this is a personal issue I have and nat directed at any one in particular. I dislike the term "emergency slips", they are slips and they are designed to allow the casing string to be properly placed in tension when, for whatever reason, it is not possible to land the casing properly using the mandrel hanger. Also, earlier Terrie provided the yield information regarding the cements employed on the well. How often are the mixes changed? As I noted in my first note to Terrie, the ultimate yields were far different from what was supplied with the permit application. These changes aren't critical, our requirement is that the well be cemented with a volume sufficient to provide 500' of fill above hydrocarbon zones. But it prompts questions when what is reported doesn't resemble what was reviewed. Maybe that final observation is more for Rob to comment on. I look forward to your reply. Tom Maunder, PE AOGCC From: Staudinger, Garret [mailto:Garret.Staudinger@bp.com] Sent: Tuesday, February 03, 2009 3:43 PM To: Maunder, Thomas E (DOA) Cc: Hubble, Terrie L Subject: RE: w-218 (208-174) Tom, Reciprocation was stopped when the mud push was at the shoe because we began loosing slack off weight (lost ~30K) so the company man decided to land the mandrel hanger on the ring. If reciprocation was not stopped at that time, we would have ran the risk of not being able to land our hanger. This would have forced us to set emergency slips. Typically, the slack off weight continues to decrease as the cement moves up the annulus due to the added friction. Let me know if this answers your question. Thanks, Garret Garret Staudinger Operations Drilling Engineer BP Exploration Alaska, Inc. Work: (907) 564-4242 Cell: (907) 440-6892 From: Hubble, Terrie L Sent: Tuesday, February 03, 2009 10:26 AM To: Maunder, Thomas E (DOA) Cc: Staudinger, Garret 2/9/2009 Page 3 of 3 Subject: RE: w-218 (208-174) Hi Tom, I can answer questions #1 and #2, Garret Staudinger should get back to you for question #3. #1. The Cement Summary for the Surface Casing job reports that the Lead cement was 623 Bbis at 3.96 Yield. #2. The Cement Summary for the 7" casing job reports that the Lead cement was 45 Bbls at 2.95 Yield. Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, February 02, 2009 4:07 PM To: Hubble, Terrie L Subject: w-218 (208-174) Terrie, I am reviewing the 407 for W-218. Some questions for you or the engineer. 1. On the surfaced cement job, what is the lead yield? 4.44 ft^3/sx is what was given in the plan but using that yield and 883 sx I don't get the 621 bbls pumped. That yield calculates to be 3.94. 2. I also have the same question on the lead for the 7". Using the 407 sack count and yield from the application (2.36), I calculate 36 bbls of cement rather than the 45 given in the operations summary. 3. On the 7" casing operation, it is stated that reciprocation was stopped when the mud push was at the shoe. Were any difficulties encountered that prevented reciprocating once cement would have been in the annulus? Thanks in advance. Tom Maunder, PE AOGCC 2/9/2009 W-218i Cementing Surface Hole Lead Production Hole Lead Permit 598 bbls 60 bbls 756 sks 142 sks 4.44 cf/sk 2.36 cf/sk Wellplan 598 bbls 50 bbls 756 sks 120 sks 4.44 cf/sk 2.36 cf/sk CADE 598 bbls 50.3 bbls 846 sks 96 sks 3.97 cf/sk 2.94 cf/sk Field Blend 621 bbls 45 bbls 880 sks 85 sks 3.96 cf/sk 2.95 cf/sk Page 1 of 2 Maunder, Thomas E (DOA) From: West, Taylor [Taylor.West@bp.com] Sent: Tuesday, February 03, 2009 5:10 PM To: Maunder, Thomas E (DOA) Cc; Sullivan, Claire; Tirpack, Robert B Subject: RE: W-218 (208-174) Tom: As requested, below is an analysis of the W-218 cement job: Problem: Cement quality across the 7" casing interval is uncharacteristically poor on new injector W- 218drilled in December 2008. Root Cause Analysis: Casing reciprocation was stopped after the mud push was pumped past the shoe, but before cement was pumped into the annulus. This was done due to reduced casing slack-off weight. The drilling and asset team believe that the probable cause of poor cement distribution is the lack of pipe reciprocation while cement was being lifted across the O-sands. Log Analysis /Utility: The USIT log reveals patchy low-side channeling across the entire logged interval. Good isolation areas exist throughout the interval in 10-40' sections interspersed between channels. Water and MI injection should be contained in the injection zone by good quality cement isolation in intervals: 8060-8120' md, 8222-8260', 9030-9040', 9330-9400' md. There are numerous sections with "adequate" isolation, 10'+ in length, -most likely adequate to prevent annular flow. Within the injection zones, good isolation exists that should prevent cross flow between O-sands: 9496-9542' md, 9656-9680' md. Remediation Analysis: Based on prior logging analysis experience and squeeze experience, it is unlikely that the channeling can be successfully squeezed. The random cement patches and disconnected channels would make a circulation squeeze or a block squeeze very challenging, and unlikely to succeed at providing additional isolation. hopefully, this explanation and our phone call will address your concerns. Thx fiaplor ~l~est Production Engineer Orion /Polaris Heavy Oil BP Exploration (Alaska}; Inc. 907.564.4647 (desk} 907.632.0111 (cell} 907.564.5016 (fax} • From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, February 02, 2009 4:34 PM To: West, Taylor Subject: W-218 (208-174) Page 2 of 2 Taylor, Is this new injector one of "yours"? Have you looked at the USIT (11/15/2008)? If this is not your well, please forward this message to the responsible party. I'd appreciate an assessment of the USIT from about 9000' down. Call or message with any questions. Tom Maunder, PE AOGCC Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, February 03, 2009 4:49 PM To: 'Staudinger, Garret' Cc: Robert Tirpack Subject: RE: w-218 (208-174) Page 1 of 2 Garret, It partially provides an answer. What were the PU and SO weights? Sometimes they are listed in the summary, but not this one. Was 30K a significant weight loss? Is there any modeling done to understand how the weights change during cementing? If I remember correctly, it has been possible to move pipe out there on most wells but I do realize that every hole section is different. For this particular well, the USIT log gives a pretty pessimistic assessment of the cement quality. There is likely sufficient isolation there to keep fluids confined to the Schrader, however isolation between the specific sands is another issue. I also have a comment regarding °slips° and this is a personal issue I have and not directed at any one in particular. I dislike the term °emergency slips°, they are slips and they are designed to allow the casing string to be properly placed in tension when, for whatever reason, it is not possible to land the casing properly using the mandrel hanger. Also, earlier Terrie provided the yield information regarding the cements employed on the well. How often are the mixes changed? As I noted in my first note to Terrie, the ultimate yields were far different from what was supplied with the permit application. These changes aren't critical, our requirement is that the well be cemented with a volume sufficient to provide 500' of fill above hydrocarbon zones. But it prompts questions when what is reported doesn't resemble what was reviewed. Maybe that final observation is more for Rob to comment on. I look forward to your reply. Tom Maunder, PE AOGCC From: Staudinger, Garret [mailto:Garret.Staudinger@bp.com] Sent: Tuesday, February 03, 2009 3:43 PM To: Maunder, Thomas E (DOA) Cc: Hubble, Terrie L Subject: RE: w-218 (208-174) Tom, Reciprocation was stopped when the mud push was at the shoe because we began loosing slack off weight (lost -30K} so the company man decided to land the mandrel hanger on the ring. If reciprocation was not stopped at that time, we would have ran the risk of not being able to land our hanger. This would have forced us to set emergency slips. Typically, the slack off weight continues to decrease as the cement moves up the annulus due to the added friction. Let me know if this answers your question. Thanks, Garret Garret Staudinger Operations Drilling Engineer BP Exploration Alaska, Inc. Work: (907) 564-4242 Cell: (907) 440-6892 2/5/2009 • From: Hubble, Terrie L Sent: Tuesday, February 03, 2009 10:26 AM To: Maunder, Thomas E (DOA) Cc: Staudinger, Garret Subject: RE: w-218 (208-174) Hi Tom, Page 2 of 2 I can answer questions #1 and #2, Garret Staudinger should get back to you for question #3. #1. The Cement Summary for the Surface Casing job reports that the Lead cement was 623 Bbls at 3.96 Yield. #2. The Cement Summary for the 7" casing job reports that the Lead cement was 45 Bbls at 2.95 Yield. Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, February 02, 2009 4:07 PM To: Hubble, Terrie L Subject: w-218 (208-174) Terrie, I am reviewing the 407 for W-218. Some questions for you or the engineer. 1. On the surfaced cement job, what is the lead yield? 4.44 ft^3/sx is what was given in the plan but using that yield and 883 sx I don't get the 621 bbls pumped. That yield calculates to be 3.94. 2. I also have the same question on the lead for the 7". Using the 407 sack count and yield from the application (2.36), I calculate 36 bbls of cement rather than the 45 given in the operations summary. 3. On the 7" casing operation, it is stated that reciprocation was stopped when the mud push was at the shoe. Were any difficulties encountered that prevented reciprocating once cement would have been in the annulus? Thanks in advance. Tom Maunder, PE AOGCC 2/5/2009 Page 1 of 1 Maunder, Thomas E (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Tuesday, January 20, 2009 3:07 PM to: Maunder, Thomas E (DOA) Cc: Makarov, Egor Subject: W-218, PTD#208-174 Hi Tom, I submitted the Completion Report for this well last week (01114/09) and I listed it as a WAG injector. I have since learned that we cannot submit Polaris wells as WAG injectors, and that it should have read Water Injector instead. As I understand it WAG injection will be requested at some future date, Please hand correct your copy. Thanks! Terrie 1 /28/2009 01/13/09 d~'~~~m~~rM~~r~ N0.5040 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 WP_II .Inh # Inn rtecrrintinn r1~fu RI r`nlnr !`rl 12-37 AZCM-00003 SBHP SURVEY ~;'~ - L_ /_ ?'~ -? - ~~ - 01/04/09 1 1 H-38 12057673 USIT {- ~, - ~: L ~'~ 12/10/08 1 1 W-218 11968975 USIT ~_ ~ - %~ L ' L/~- (G 12/11/08 1 1 Z-09A 08AKA0020 OH MWD/LWD EDIT _ ~~, -~~-// - ~ /_. ~ =~ 10/16/08 2 1 MLtNJt AI:KNUWLtUIit Iitl;tlY1 t3T SICiNIN(a ANU Mtl UtiNINCi UNt LUNY tAt:rt I U: BP Exploration (Alaska) Inc. - Petrotechnical Data Center LR2-1 ' _. ._ _, 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: °` Alaska Data & Consulting Services 2525 Gambell Street, Suite 40Q Anchorage, AK 99503-2838 ATTN: Beth ~ J Received by: ~ ~~..---'"°'~ ~\ STATE OF ALASKA ~y 1 ALASK~L AND GAS CONSERVATION COSIGN `` r WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~°~~~ ~ ,~ .~i~s 2©09~ INJ CTOR 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.,os zoAACZS.,,o ^ GINJ WINJ ^ WDSPL ^ Other No. of Completions One 1b. V~ell`CI Ms`s ~ ~ '~.Oli~b 0 ^ Developm4tt~dt~~ploratory ®Service ^ Stratigraphic 2. Operator Name: ~ ~~ oc~\„~ o,~ BP Exploration (Alaska) Inc. ~, ° ,,~ 5. Date Comp., Susp., or Aband. 12/14/2008 12. Permit to Drill Number 208-174 3. Address: ~ P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11/25/2008 13. API Number 50-029-23403-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/6/2008 14. Well Name and Number: PBU W-218 FEL, SEC. 21, T11N, R12E, UM 4964 FSL, 1175 Top of Productive Horizon: 1364' FSL, 306' FWL, SEC. 10, T11 N, R12E, UM 8. KB (ft above MSL): 81.7' Ground (ft MSL): 53.2' 15. Field /Pool(s): Prudhoe Bay Field /Polaris Pool Total Depth: 1921' FSL, 330' FWL, SEC. 10, T11 N, R12E, UM 9. Plug Back Depth (MD+TVD) 9985' 5317' 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 612049 y- 5959941 Zone- ASP4 10. Total Depth (MD+TVD) 10080' 5367' 16. Property Designation: ADL 028263 & 028261 TPI: x- 613410 y_ 5966922 Zone- ASP4 th: x- 613425 - 5967478 Zone- ASP4 Total De 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: p y 18. Directional Survey ®Yes ^ No ubmit I ctr ni n rin inf i n r 2 AAC 2 .050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 2091 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD GR, MWD GR / RES / NEU / AZI DEN / PWD, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 0" 1. A- urfa 108' 1 4 " 6 sx Ar i et A r x. " 41 4" r I ' To J 212s A i ie 7" 26# - 0 1 071' 6' 8-1/ " x Lite r 4 x l ' 23. Open to production or inject ion? ®Yes ^ No 24. TU81NG RecoRo If Yes, IISt each I (MD+TVD of To & Bottom Pe nterval Open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD ; p 4-1/2" Gun Diameter 5 spf 3-1/2", 9.2#, L-80 9902' 9377', 9535' & 9700' , MD TVD c'~3't'1 MD TVD 9435' -9480' 5033' - 5055' 455 9606' - 9650' 511 T - 5140' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. II'~'~ 9710' - 9785' 5172' - 5212' ~~~ V DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protect w/ 113 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^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. y,., a None /o1~%Y-=0 ~ ~~~~ r I'a"~ x ~.. ,,, Form 10-407 Revised 02/2007 C N N E E I E 28. GEI3LOGIC MARKERS (LIST ALL FORMATIONS AN RS ENCOUNTERED): 29. FORMATION TESTS NAME M TVD Well Tested? ^ Yes ®No Permafrost Top 28.5' 28.5' If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 2119' 1981' detailed test information per 20 AAC 25.071. Ugnu 5618' 3480' None Schrader Bluff NA 8978' 4810; Schrader Bluff NB 9027' 4833' Schrader Bluff NC 9094' 4866' Schrader Bluff NE 9115' 4876' Schrader Bluff NF 9224' 4930' Schrader Bluff OA 9304' 4969' Schrader Bluff OBa 9429' 5030' Schrader Bluff OBb 9498' 5063' Schrader Bluff OBc 9597' 5112' Schrader Bluff OBd 9709' 5171' Schrader Bluff OBe 9835' 5238' Schrader Bluff OBf 9920' 5283' Base Schrader Bluff OBf / 10032' 5341' Top Colville Mudstone Formation at Total Depth (Name): Colville Mudstone 10032' 5341' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore ing is true and correct to the best of my knowledge. O' ~Q (( ~13~~ Signed Terrie Hubble Title Drilling Technologist Date PBU W-218 208-174 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A ro a Drilling Engineer: Garret Staudinger, 564-4242 INSTRUCTIONS GeNeRA~: 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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelty 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: 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. IreM 29: 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. Y~1 I Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: W-218 Common Name: W-218 _ _ Test Date Test T ype ~ Test De th MD p (T ) Test De th VD P R ) AMW Surface Pressure ( ) Leak Off Pressure BHP , EMW 12/5/2008 LOT __- 5,461.0 (ft) - -- 3,418.0 (ft) 8.80 (ppg) 970 (psi) 2,533 (psi) 14.26 (ppg) • Printed: 12/30/2008 12:39:08 PM f M BP EXPLORATION Operations Summary Report Legal Well Name: W-218 Page 1 of 15 ~ Common Well Name: W-218 Spud Date: 11/25/2008 Event Name: DRILL+COMPLETE Start: 11/24/2008 End: 12/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/14/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/24/2008 100:00 - 01:30 1.501 RIGD P PRE 01:30 - 03:00 1.50 RIGD P PRE 03:00 - 04:00 1.00 MOB P PRE 04:00 - 05:30 1.50 MOB P PRE 05:30 - 08:00 2.50 MOB P PRE 08:00 - 10:30 2.50 MOB N WAIT PRE 10:30 - 15:00 4.50 MOB P PRE 15:00 - 16:00 1.00 MOB P PRE 16:00 - 17:00 1.001 RIGU P PRE Prepare for rig move. -Secure cellar -Prep walkways and stairs *Move camp and shops to W-Pad from V-Pad Bridal up derrick and secure rig floor. PJSM with Peak hands and rig crew. Move Pit Complex away from rig. Raise and move rig off of V-219 and stage near V-Pad access road. Move Pit Complex from V-Pad and stage on W-Pad. -Lower Derrick on Substructure while moving Pits. Wait on Security to escort Substructure. Move Sub from V-Pad to W-Pad. Move in and spot Sub on W-218. -Lay rig mats and herculite. -Secure cellar. PJSM. Raise and pin Derrick. -Raise cattle shute and level Sub. 17:00 - 18:30 1.501 RIGU P PRE 18:30 - 20:30 I 2.001 RIGU ~ P ~ ~ PRE 20:30 - 23:00 2.50 RIGU P PRE 23:00 - 00:00 1.00 RIGU P PRE 111/25/2008 ~ 00:00 - 04:30 ~ 4.50 ~ RIGU ~ P ~ ~ PRE 04:30 - 10:00 5.50 RIGU P PRE 10:00 - 10:30 0.50 RIGU P PRE 10:30 - 12:00 1.50 RIGU P PRE 12:00 - 13:00 1.00 RIGU P PRE 13:00 - 13:30 0.50 RIGU P PRE 13:30 - 15:30 2.00 RIGU P PRE 15:30 - 17:00 1.50 RIGU P PRE 17:00 - 18:00 1.00 RIGU P PRE 18:00 - 18:30 0.50 RIGU P PRE 18:30 - 00:00 5.50 DRILL P SURF Move in, spot, and level Pit Complex. -Clear all walkways. -Begin loading 5" Drillipipe in shed and strapping. Hook up interconnect, steam, and water lines. -Spot cuttings tank, MWD shack, Mud shack, and Geo shack. -Take on water in Pits. Bridle down and hook up Top Drive. -Rig up rig tongs, hydraulic service loops, and kelly hose. Nipple up Diverter System. -Change out 12" air boot to 20" adapter. -Install 4" valves on conductor. Continue to Rig Up. -Nipple up Surface Riser. -Continue to strap 5" Drill Pipe. -Build Spud Mud. Pick up 5" Drill Pipe 1x1 and stand back in Derrick. Hold Pre-Spud Meeting with BP WSL Brian Buzby and Rig Crew. Continue to pick up 5" drill pipe and 5" HWDP 1x1 and stand back in derrick. Make up Jar Stand and Drill Collar Stand and rack back in derrick. Perform Diver3e~Test with NAD TP Kelly Cozby -good. -AOGCC Representative Chuck Scheve waived witness of test. Make up 12-1/4" Drilling BHA #1 as per directional driller. PJSM. Rig up Sperry Wireline Unit and Gyrodata Clean and clear rig floor. Fill hole and check for leaks -good. Pressure test mud lines to 3000 psi -good. Spud W-218 ~ 18:30 hrs and drill from 108' to 366'. -596 gpm ~ 890 psi. -45 rpm ~ 1 k TO. rnncea: mauizuva icoa: iw rm r BP EXPLORATION Page 2 of 15 Operations Summary Report Legal Well Name: W-218 Common Well Name: W-218 Spud Date: 11/25/2008 Event Name: DRILL+COMPLETE Start: 11/24/2008 End: 12/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/14/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To ~ Hours Task !Code , NPT ~ Phase Description of Operations 11/25/2008 18:30 - 00:00 5.50 DRILL P SURF -60k Up Wt, 50k Dn Wt, 55k Rot Wt. 11/26/2008 00:00 - 01:30 1.50 DRILL P SURF POH from 366' and pick up Non-magnetic Drill Collar Stand and Jar Stand. RIH to 366' with no problems. 01:30 - 03:30 2.00 DRILL P SURF Drill ahead from 366' to 465'. -584 gpm ~ 1000 psi. -15-20k WOB. 03:30 - 06:00 2.50 DRILL N DFAL SURF err r in toolface readin . -Gyro toolface reading 200 degrees off from MWD toolface. -Troubleshoot UBHO sleeve -good. -Troubleshoot Gyro tool -good. -Lay down MWD tool. 06:00 - 08:30 2.50 DRILL N DFAL SURF Make u BHA #2 s per Directional Driller and RIH to 465'. -Pick up new MWD tool. -Scribe in hole and take survey. Gyro, MWD, and scribe line all matching up. 08:30 - 00:00 15.50 DRILL P SURF Directionally drill ahead from 465' to 1777'. -596 gpm ~ 1420 psi off, 1600 psi on. -50 rpm ~ 4.5k TO off, 6.8k TO off. -25k WOB -108k Up Wt, 90k Dn Wt, 95k Rot Wt. -Backream 30' on connections and survey every stand. -Wood over shakers from 400' to 700'. 'Ran Gvro every stand until 927' then riaaed down Wireline 11/27/2008 00:00 - 01:00 1.00 DRILL P SURF Drill ahead from 1777' to 1965'. -596 gpm ~ 1420 psi off, 1600 psi on. -50 rpm ~ 4.5k off, 6.8k on. -25k WOB -108k Up Wt, 90k Dn Wt, 95k Rot Wt -Backream 30' on connections and survey every stand. 01:00 - 02:00 1.00 DRILL P SURF CBU x3 ~ 600 gpm, 1650 psi. -55 rpm ~ 5.5k TO -Reciprocate pipe 90' strokes. -Mo tl sand comin over shakers with small amo nts 02:00 - 05:00 3.00 DRILL P SURF POH from 1965' to top of BHA #2. -Encounter tight spot ~ 1145'. Pull 50k over. Screw in and backream from 1145' to 1014' C~ 50 rpm, 2.2k TO, 600 gpm, 1200 psi. -Pull from 1014' to 539' and encounter intermittent tight spots. Pulling 10k-30k over. Work through without problems. -Encounter tight spot ~ 539' pulling 50k over. Backream from 539' to 357' at same parameters. 05:00 - 06:00 1.00 DRILL P SURF Stand back BHA #2 and lay down bit. -Bit graded 5-7-SS-A-E-2-NO-TD 06:00 - 10:00 4.00 DRILL P SURF Pick up new 12-1/4" bit and RIH to 1965'. Rcn into obctr~ tion C~ 1100' Wash and ream down from - 1100' to 1500' and work ast r 10:00 - 00:00 14.00 DRILL P SURF Directionally drill ahead from 1965' to 4136'. -650 gpm ~ 1960 psi off, 2250 psi on -50 rpm ~ 5.5k TO off, 8.5k TO on -25k WOB -125k Up Wt, 80k Dn Wt, 97k Rot Wt rnntea: iaawcuuo ic:ay.ir nvi f ~ BP EXPLORATION Page 3 of 15 Operations Summary Report Legal Well Name: W-218 Common Well Name: W-218 Spud Date: 11/25/2008 Event Name: DRILL+COMPLETE Start: 11/24/2008 End: 12/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/14/2008 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To '~ Hours Task ~ Code j NPT Phase Description of Operations 11/27/2008 10:00 - 00:00 14.00 DRILL P SURF 11/28/2008 00:00 - 06:00 6.00 DRILL P SURF 06:00 - 12:00 6.001 DRILL ~ N ~ STUC ~ SURF 12:00 - 16:00 I 4.001 DRILL I N I STUC I SURF 16:00 - 19:00 3.001 DRILL P SURF 19:00 - 00:00 5.001 DRILL P SURF 11/29/2008 109:30 - 20:30 11.001 DRILL P SURF 20:30 - 22:30 I 2.001 DRILL I P 22:30 - 00:00 I 1.501 DRILL I P 111/30/2008 100:00 - 00:30 0.501 DRILL P -Backream 30' on connections and survey every stand. Drill ahead in 12-1/4" Surface hole from 4136' to 4703' -650 gpm ~ 2050 psi off, 2349 psi on. -60 rpm ~ 8.6k TO off, 11.5k TO on -25k WOB -140k Up Wt, 80k Dn Wt, 100k Rot Wt. -Backream 30' on connections and survey every stand. 'Experienced 200 psi pressure drop after making connection C~3 4440'. Troubleshoot and found no surface leaks. Pressure maintained constant at drilling rate. Addition of De-Foamer in drilling mud possible cause of pressure drop. Stuck BHA while backreaming 30' on connection ~ 4690'. -Work pipe and attempt to free string -Torque and Slump. -Attempt to regain circulation -Unable. Iniecting ~ 1100 psi ~ 1 bpm• -Circulation established ~ 11:30 hrs with 1.5% return flow ~ 1228 psi, 52 gpm. Continue to work drillstring and free stuck BHA. -Pump 2 sweeps of 50 bbl ScreenKleen Pills. -Stage up pumps and re-establish circulation to 550 gpm with full returns. -Still unable to free pipe with jarring. Unable to rotate. -Jar pipe ~ 300k and pull to 400k Ibs -pull BHA free. -Full circulation and rotation established. CBU x4 ~ 540 gpm, 1880 psi. -90 rpm ~ 8.8k TO. -Reciprocate pipe 90' strokes. `Inspect derrick after jarring -good. Backream from 4703' to 3947' -650 gpm ~ 2000 psi. -100 rpm ~ 9.5k TO. -140k Up Wt, 80k Dn Wt, 106k Rot Wt. -Adjust backreaming speed from 30 to 300 fph as hole conditions allow. Directionally drill ahead from 4703' to TD ~ 5471'. -650 gpm ~ 2260 psi on, 2150 psi off. -100 rpm ~ 13-14k TO on, 11-12k TO off. -25-30k WOB -190k Up Wt, 75k Dn Wt, 105k Rot Wt. -Backream 95' on connections and survey every 90'. SURF CBU x3 ~ 650 gpm, 2210 psi. -100 rpm ~ 12k TO. -110k Rot Wt. -Reciprocate pipe 30', keeping bit in shale. -Shakers clean after 3rd tt m -Monitor well -static. SURF Backream from 5471' to 5174'. -650 gpm ~ 2185 psi. -80 rpm ~ 108k TO. -165k Up Wt, 80k Dn Wt, 105k Rot Wt. SURF Continue to backream out from 5174' to 4703'. Nrinted: iuswzuu~s iz:'sa:i4 rnn BP EXPLORATION Page 4 of 15 Operations Summary Report Legal Well Name: W-218 Common Well Name: W-218 Spud Date: 11/25/2008 Event Name: DRILL+COMPLETE Start: 11/24/2008 End: 12/14/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2008 Rig Name: NABORS 9ES Rig Number: Date From - To Hours ', Task Code NPT Phase Description of Operations 11/30/2008 00:00 - 00:30 0.50 DRILL P SURF -650 gpm ~ 2185 psi. -80 rpm ~ 108k TO. 00:30 - 01:00 0.50 DRILL P SURF RIH from 4703' to TD ~ 5471' with no roblems., 01:00 - 01:30 0.50 DRILL P SURF Circulate ~ 650 gpm, 2200 psi. 01:30 - 07:30 6.00 DRILL P 07:30 - 13:00 5.50 DRILL P 13:00 - 15:00 2.00 DRILL P 15:00 - 16:00 1.00 DRILL P 16:00 - 18:00 2.00 CASE P 18:00 - 19:00 ~ 1.00 CASE ~ P 19:00 - 19:30 0.50 ~ CASE ~ P 19:30 - 00:00 I 4.50 I CASE I P 112/1/2008 100:00 - 14:30 ~ 14.50 ~ CASE ~ P -100 rpm ~ 12.5k TO. -Reciprocate pipe 30' strokes. SURF Pump out of hole from 5471' to 1945' -650 gpm, 1975 psi. SURF POH from 1945' to top of BHA #3. -Attem t to ull d but over ullin 25k-35k lbs. -Continue to pump out to 1150'. Encountered tight spots C~3 1895', 1735', and 1458'. Work pipe and wipe through spots - ok. -Pull dry from 1150' to top of BHA #3. SURF Lay down BHA #3 as per directional driller. SURF Clean and clear rig floor. SURF Ri u to run 9-5/8" Casin with Tesco Casin Drive S ste -Remove bails and elevators. -Make dummy run with hanger and landing joint -good. -Bring Tesco equipment to rig floor and rig up. SURF Run 9-5/8" 47# L-80 BTC Casin as per running tally. -Torque connections to 25k ft-Ibs (Torque Rings installed in BTC box end). -Baker Lok shoe track. SURF Safety Stand Down. -Hold safety meeting with crew after finger injury on rig floor while removing thread protectors. -Discuss hand placement, communication, and focus while working with others. SURF Continue to run 9-5/8" 47# L-80 BTC Casing as per running tally with Tesco CDS to 1479'. -Torque connections to 25k ft-Ibs (Torque Rings installed in BTC box end). -Run free floating Hydroform centralizers on first 5 joints. -Dope with BOL-2000. -Fill pipe every joint and circulate every 10 jts. -Encountered tight spot ~ 1185' and work through.. -Encounter intermittent tight spots from 1300' to 1400'. Work and wash down ~ 130 gpm, 180 psi. SURF Continue to run 9-5/8" 47# L-80 BTC Cs with Tesco CDS froi 1479' to 5461' -Torque connections to 25k ft-Ibs (Torque Rings installed in BTC box end). -Dope with BOL-2000. -Fill pipe every joint and circulate every 10 jts. -Encountered tight spot from 1720' to 1800'. Work pipe and wash down ~ 140 gpm, 238 psi. Hole attempting to pack off. Stuck i e ~ 1747', but able to work free. Continue to wash and work pipe -able to work through. Regain full returns. -Intermittent tight spots from 2000' to 2150'. Wash down and work pipe through. No problems after 2150'. Nnntea: izisurtuus ic~aaa rm BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: W-218 Common Well Name: W-218 Spud Date: 11/25/2008 Event Name: DRILL+COMPLETE Start: 11/24/2008 End: 12/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/14/2008 Rig Name: NABOBS 9ES Rig Number: i Date ~ From - To i Hours Task !Code NPT ~~ Phase Description of Operations 12/1/2008 _ 00:00 - 14:30 14.50 CASE P SURF -Pick up casing with torque and begins rotating with surface_ torque at 24-25.000shut down rotary. -Circulate without rotating for 15 minutes,attempt rotation, max torque set at 25k. -Pick up string with torque, rotation is intermittent,shut down rotary. -Make u han er and landin 'oint. Land casin on rin . -250k Up Wt, 125k Dn Wt. 14:30 - 18:30 4.00 CEMT P SURF Stage up pumps and circulate at 5 bpm, 575 psi. -Reci rocate 15' strokes. -Condition mud to 9.5 ppg, 65 vis, 17 YP. 18:30 - 19:30 1.00 CEMT P SURF Blow down Tesco tool and Top Drive. -Rig down Kelly Hose and rig up cement hose to Top Drive. 19:30 - 20:00 0.50 CEMT P SURF Hold PJSM with rig crew and SLB cementing crew. -Continue working pipe 10' strokes. 20:00 - 23:30 3.50 CEMT P SURF Switch over to Schlumberger. -Pump 4 bbls of 10.0 ppg Mudpush II. Pressure test lines to 4000 psi - OK. -Pump 71 bbls of 10.0 ppg of Mudpush II ~ 5 bpm, 300 psi. -Shut down and unsting Tesco tool from landing joint. Drop bottom plug and sting Tesco tool back into landing joint. -Pump 621 bbls of 10.7 ppg DeepCrete lead cement ~ 6 bpm, 360 psi ICP, 630 psi FCP. Reduce rate to 5 bpm, 490 psi ICP, 770 psi FCP ~ 515 bbls into pumping lead due to pressure loss. -Pum 86 bbls of 15.8 Class "G" tail cemen ~ 4.5 bpm, 930 psi ICP, 1240 FCP. -Unsting from landing joint and drop top plug. Sting back into landing joint chase with 10 bbls H2O. _ Full returns throughout cement pumping. 'Reci rocated i e in 10' strokes. Land on rin 440 bbls into um in lead cement due to low slack off wei ht. 23:30 - 00:00 0.50 CEMT P SURF Switch over to rig pumps and begin displacing cement with 131 bbls 9.5 ppg Spud Mud ~ 3 bpm, 1250 psi ICP, 1330 psi FCP. -At 1100 strokes into displacement, increase rate to 4 bpm, 1465 psi ICP, 1440 psi FCP. 12/2/2008 00:00 - 02:00 2.00 CEMT P SURF Continue dis lacement of cement with total of 384 bbls 9.5 Spud Mud @ 5 bpm, 330 psi ICP, 780 psi FCP. -At 2100 strokes -decrease rate back to 3 bpm, 1215 psi ICP, 1590 psi FCP due to pressure loss ~ 4 bpm. -At 4100 strokes -decrease to 2 bpm, 1590 psi ICP, 1965 psi FCP. -At 4700 strokes -hole packed off with no returns to surface_., -At 4950 strokes -divert flow to cellar to ensure landing ring was not packed off. No flow in cellar. -Bumped plug ~ 5538 strokes at 2900 psi and pressure up to 3350 si - hold for 2 minutes. -Bleed off pressure and check floats - ok. 9-5/8" casing shoe ~ 5461'. CIP ~ 01:48 hrs. No cement or Mudpush back to surface. rnntea: m~urzwu ¢sa: iw rm ~ ~ BP EXPLORATION Page 6 of 15 Operations Summary Report Legal Well Name: W-218 Common Well Name: W-218 Spud Date: 11/25/2008 Event Name: DRILL+COMPLETE Start: 11/24/2008 End: 12/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/14/2008 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To ~ Hours Task ~i Code i, NPT ~~, Phase ~ Description of Operations 12/2/2008 00:00 - 02:00 2.00 CEMT P 02:00 - 02:30 0.50 CEMT P 02:30 - 05:00 2.50 CEMT P 05:00 - 07:30 2.50 DIVRTR P 07:30 - 09:30 2.00 DIVRTR P 09:30 - 10:30 1.00 CEMT P 10:30 - 12:00 1.50 CEMT P 12:00 - 19:00 I 7.001 CEMT 1 P SURF SURF SURF SURF SURF SURF SURF Notified AOGCC that cement did not return to surface and obtained approval for remedial top job. Pressure test 9-5/8" casing to 3500 psi for 30 minutes -good. Flush riser. Break and re-torque landing joint to 1000 ft-Ibs and lay down. PJSM with TESCO. Rig down Tesco tool and service loop. Clean the rig floor drain pan. Remove the riser, dresser sleave and diverter stack. Change out top drive quill from 5" to 4". Service top drive. Wait for tools and equipment to arrive on location for remedial cement top job. Safety Stand Down. -Discuss plan to improve hand safety on the rig. -Discuss good communication tactics. -Discuss proper time to join a job currently in progress. Bring handling equipment to rig floor. Make up 220' of 1 "pipe and run down 9-5/8" casing x 20"_ conductor annulus for top job. l lnahla to run 1" nine deeper than 220'. Dick uo to 210' for top SURF 19:00 - 20:00 1.001 CEMT N SFAL SURF 20:00 - 21:30 I 1.501 CEMT I P I I SURF 21:30 - 22:00 0.50 CEMT P SURF 22:00 - 00:00 2.00 CEMT P SURF 12/3/2008 00:00 - 01:00 1.00 CEMT P SURF 01:00 - 03:00 2.00 WHSUR P SURF 03:00 - 07:00 4.00 BOPSU P SURF 07:00 - 08:00 1.00 BOPSU~P SURF 08:00 - 09:00 1.00 BOPSU P SURF Rig up cement lines. Blow air down hard lines. Ice plug in Schlumberger's lines. Replace line. Test lines to 1000 psi with 10 bbls of fresh water. Begin mixing 10.7 ppg cement for top job. Pump cement at 2 bpm, 700 psi. Thick. clabbered up, 9.5 ppg mud returns through out top job. Returns taken into cellar and pumped out with Vac truck and Super Sucker. 10.7 ppg cement returned to surface after 175 bbls of cement away Total of 181 bbls of cement pumped. Cement to surface witnessed by AOGCC rep John Crisp, BP WSL Kris Honas, and Nabors Tool Pusher Brian Tiedemann. Blow down all cement lines. Rinse and lay down 210' of 1" pipe from top job. Clean and clear the rig and cellar. Prep cellar area to nipple up wellhead and BOP stack. Nipple up the FMC casing, and tubing spools. -Test metal to metal seal to 1000 psi for 10 minutes. Nipple up the BOP's. -Position BOP stack over well head. -Torque flange bolts. -Install the riser. Pick up test tools and flush stack. Safety Stand Down /After Action Review. -Discuss ownership of tasks. -Discuss steps for improving communication. -Perform after action review on nippling up BOP stack. Nnnteo: iziswzuua ic~aan rm BP EXPLORATION Page 7 of 15 Operations Summary Report Legal Well Name: W-218 Common Well Name: W-218 Spud Date: 11/25/2008 Event Name: DRILL+COMPLETE Start: 11/24/2008 End: 12/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/14/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours i Task Code NPT Phase Description of Operations 12/3/2008 08:00 - 09:00 1.00 BOPSU~ P SURF 09:00 - 16:00 7.00 BOPSU P SURF 16:00 - 17:00 1.00 BOPSUp P SURF 17:00 - 23:00 6.00 DRILL P SURF 23:00 - 00:00 1.00 DRILL P SURF 12/4/2008 00:00 - 00:30 0.50 DRILL P SURF 00:30 - 05:00 4.50 DRILL P SURF 05:00 - 06:00 1.00 DRILL P SURF 06:00 - 07:30 1.50 DRILL P SURF 07:30 - 19:00 11.50 DRILL P SURF 19:00 - 20:30 1.50 DRILL P PROD1 20:30 - 00:00 3.50 DRILL N SFAL PROD1 12/5/2008 00:00 - 01:00 1.00 DRILL N SFAL PROD1 01:00 - 01:30 0.50 DRILL P PROD1 01:30 - 07:30 6.00 DRILL P PROD1 07:30 - 09:00 ~ 1.50 ~ DRILL ~ P ~ ~ PROD1 Meeting attended by BP WSL Blair Neufeld and Nabors Tool Pusher Kelly Cozby. Fill stack and lines. Test BOP's with 4" & 3.5" test joint to 250 psi low, 4000 psi -Test witness waived by AOGCC rep John Crisp. -Test witnessed by Nabors TP Kelly Cozby and Brian Tiedemann. -Test witnessed by BP WSL Blair Neufeld. Lay down test tool. Rig down test equipment. Blow down lines. Install wear ring. RIH with 4992' of 5" drill pipe and HWDP out of the derrick. Lay down jars from surface hole and pick up new jars. Circulate bottoms up to remove thick spud mud prior to picking up 4"drill pipe. -390 gpm, 650 psi, 35 RPM, Pump a dry job. Blow down top drive. Pull out of hole laying down 5" drill pipe singles from 4992' MD. Slip and cut 91 feet of drilling line. RIH with remaining 4 stands of 5" drill pipe from derrick. lay down 12 joints of 5" drill pipe and 18 joints of 5" HWDP Pick up 307 joints of 4" drill pipe and stand back in the derrick. -Adjust Kelly Hose to allow drill pipe to be racked in derrick. PJSM on picking up BHA. -Make up bit, 1.5 degree bent motor, and MWD. -Orient MWD to motor. -Begin loading ADN source. Unable to load source into ADN tool. -Attempt to engage source in ADN tool 5 times. -Pull source out of ADN and see that "cap" (used to screw source onto ADN tool) is missing. -Work with MWD supervisor to discuss options. -Wait for a new source to be sent out of Dead Horse as well as parts and tools to attempt to repair current source (2 hr wait) -Run a camera down MWD tool to ensure "cap" did not fall off source and down MWD: No cap in MWD. -Clear all rig crew from floor and dog house, Allow MWD ....,supervisor and MWD hands to remove source from lead 'container and put a new "cap" on the source. -Finish repairing Source. -Load original source in ADN tool. Finish picking up remaining 8.5" drilling BHA -Pick up 3 NM drill collars, saver sub, and jars. RIH with 8.5" drillin BHA to 1600' MD. -Shallow hole test the MWD tools -450 GPM, 1150 psi. Continue to run in hole with BHA picking 4" drill pipe singles. Wash down from 5261' -PU 135K, SO 68K, ROT 94K. Pri ntea: tv~uizuuts iz:'sa:ia rm • BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: W-218 Common Well Name: W-218 Spud Date: 11/25/2008 Event Name: DRILL+COMPLETE Start: 11/24/2008 End: 12/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/14/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/5/2008 107:30 - 09:00 ~ 1.501 DRILL ~ P 09:00 - 09:30 0.50 DRILL P 09:30 - 10:00 0.50 DRILL P 10:00 - 00:00 I 14.001 DRILL I P 12/6/2008 100:00 - 18:00 I 18.001 DRILL I P 18:00 - 19:00 1.00 DRILL P 19:00 - 00:00 I 5.001 DRILL I P 112/7/2008 100:00 - 05:00 I 5.001 DRILL I P 05:00 - 06:00 1.00 I DRILL P PROD1 -500 GPM, 2750 psi, 60 RPM, 6-7K WOB. Ta cement at 5367' MD. -Drill shoe track +20 foot of new formation to 5491' MD. -Start Swapping mud over to 8.8 ppg LSND while drilling rat hole. PRODi Finish mud swap to 8.8 ppg LSND drilling fluid. -460 GPM, 1234 psi. PROD1 Perform LOT to 14.27 EMW. -8.8 ppg drilling fluid. -927 psi surface pressure. -3418' TVD. PROD1 Drill 8.5" production hole from 5491' to 7556' MD. -550 GPM, 2695 psi on, 2550 psi off. -10-20K WOB, 100 RPM, 9K Tq on, 8K Tq off. -Backream 90' prior to connections. -Survey every 90'. -Calculated ECD = 9.76 ppg EMW. -Actual ECD = 10.58 ppg EMW. -Actual Rotate Time = 5.36 hrs. -Actual Slide Time = 0.72 hrs. -Mud weight in/out 8.9 ppg. Pump high vis sweeps at 6600', 7078', and 7555' MD. -20% increase in cuttings on first sweep. -5-10% increase in cuttings on following sweeps. PROD1 Drill 8.5" production hole from 7556' to 10,080' MD. -550 GPM, 3527 psi on, 3402 psi off. -5-10K WOB, 100 RPM, 10K Tq on, 8K Tq off. -Backream 90' prior to connections. -Survey every 90'. -Calculated ECD = 9.89 ppg EMW. -Actual ECD = 10.61 ppg EMW. -Actual Rotate Time = 8.68 hrs. -Actual Slide Time = 2.54 hrs. -Mud weight in/out 9.2+ ppg. PROD1 Circulate an open hole volume prior to backreaming. -550 GPM, 3320 psi, 100 RPM, 8.3K Tq. -Pump a 25 bbls high vis sweep. PROD1 Backream out the 8.5" production hole. -PU 168K, SO 96K (No Pumps). -PU 158K, SO 92K, ROT 118K (With Pumps). -550 GPM, 3265 psi, 100 RPM, 8K Tq. -975 ft/hr -MAD pass at 300 ft/hr from 9625'-9550' MD and 9030'-8985' MD (bit depth). PROD1 Continue to backream out of the 8.5" production hole to 5461' MD. -550 GPM, 2005 psi, 100 RPM, 5.8K Tq. -PU 118K, SO 74K, ROT 92K. PROD1 Circulate a bottoms up inside the 9-5/8" shoe while slowly Printetl: 12/30/2008 12:3~J:14 PM ~ ~ BP EXPLORATION Page 9 of 15 Operations Summary Report Legal Well Name: W-218 Common Well Name: W-218 Spud Date: 11/25/2008 Event Name: DRILL+COMPLETE Start: 11/24/2008 End: 12/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/14/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/7/2008 05:00 - 06:00 1.00 DRILL P PROD1 pulling two stands to 5261' MD. -500 GPM, 1950 psi. 06:00 - 06:30 0.50 DRILL P PROD1 Monitor the well: Static. Mud weight in/out =9.3 ppg. Pump a dry job and blow down top drive. Pull out of hole with 8.5" drilling BHA. 06:30 - 09:00 2.50 DRILL P PROD1 Pull out of hole from 5261' to 285' MD. 09:00 - 12:30 3.50 DRILL P PROD1 Lay down 8.5" drilling BHA including: Jars, saver sub, NM drill collars, stabilizer, MWD with DIR/GR/RES/DEN/NEU, 1.5 degree motor, and bit. -Bit graded: 1-2-WT-A-X-1-CT-TD. 12:30 - 15:00 2.50 BOPSU P RUNPRD Flush the stack. Pull the wear ring. Install test plug with 7" test joint. Test rams to 250 psi low and 3500 psi high. Lay down test joint. ~ 15:00 - 17:00 2.00 CASE P RUNPRD Make a dummy run with the 7" hanger. Rig up to run 7", 26 Ib/ft, L-80, IBT-M/TCII casing. -Make up Franks tool and 350 ton running tool. 17:00 - 00:00 7.00 CASE P RUNPRD RIH with 7", 26 Ib/ft, L-80, IBT-M casing to 2608'. -Bakerlok shoe track and check floats. -Use Best-O-Life 2000 NM dope on each connection. -Average Make up torque 9500 ft-Ibs for BTC connections. -1.5 to 2 min/joint running speed adjusting based on displacement. -Record PU / SO every 10 joints. 12/8/2008 00:00 - 07:00 7.00 CASE P RUNPRD RIH with 7". 26 Ib/ft. L-80. IBT-M/TCII casina to 5442' MD. -Use Best-O-Life 2000 NM dope on each BTC connection. -Average Make up torque 9500 ft-Ibs for BTC connections. -1.5 to 2 min/joint running speed adjusting based on displacement. --1 bbl under on displacement every 10 joints up to 9-5/8" shoe. -Record PU / SO every 10 joints. -RA marker in collar 789' from shoe. -Cross over to TCII 3089' from shoe. -Make up TCII connections to 10,100 ft-Ibs. -Use Jet Lube Seal Guard dope on TCII connections. 07:00 - 08:00 1.00 CASE P RUNPRD Circulate 1.5x bottoms up at 9-5/8" shoe. -5 bpm, 590 psi. -No losses. 08:00 - 19:30 11.50 CASE P RUNPRD RIH with 7" 26 Ib/ft L-80 TC-II casin to 10 071' MD. -1.5 to 2 min/joint running speed adjusting based on displacement. -Pro er dis lacements from 9- 8" -Record PU / SO every 10 joints. -Make up TCII connections to 10,100 ft-Ibs. -Use Jet Lube Seal Guard dope on TCII connections. -Break circulation every 15 joints. -Fill casing every joint. 19:30 - 20:00 0.50 CASE P RUNPRD Land casina hanoer on ring. -PU 258K, SO 102K. Printetl: 12/30/2008 12:3y:14 PM • • BP EXPLORATION Page 10 of 15 Operations Summary Report Legal Well Name: W-218 Common Well Name: W-218 Spud Date: 11/25/2008 Event Name: DRILL+COMPLETE Start: 11/24/2008 End: 12/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/14/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/8/2008 19:30 - 20:00 0.501 CASE P 20:00 - 23:00 I 3.001 CEMT I P 23:00 - 00:00 1.00 CEMT P 12/9/2008 100:00 - 02:00 2.00 CEMT P 02:00 - 03:00 I 1.00 I CASE I P 03:00 - 05:30 2.501 WHSUR P 05:30 - 13:00 I 7.501 WHSUR I P RUNPRD Lay down the Franks fill-up tool. Make up cement head. RUNPRD Slowly stage pumps up to 5 bpm. -210 gpm, 872 psi. -Reci rocate i e 15': PU 225K SO 86K. -Pressure slowly came down -75 psi and leveled off. Rig up SLB cement lines and hold PJSM while circulating. Start hatching up at 22:00. RUNPRD Set casing string on ring and pump 10 bbls of MUD push with SLB pumps. -Pressure test lines to 4500 psi. -Bleed off pressure. Pump a total of 37.7 bbls of MUD Push at 10 ppg, 660 psi. Drop bottom plug. -5 bpm, 850 psi. Pum 72 bbls of 15.8 tail cement -5 bpm, 1200 psi. RUNPRD Continue to pump 15.8 ppg Class G tail cement. Wash down SLB cement lines with water down the flow line. Drop Bottom plug and Begin displacement with 9.0 ppg brine using the rig pumps. -Chase cement at 5 bpm for 590 strokes. -Continue to displace cement with 9.0 brine. -Reciprocate pipe 15' -5 bpm, 780 psi. Sto reci rocatin at 3900 strokes MUD Push at shoe . Reduce rate to 3 bpm, 1316 psi after 5420 strokes. Reduce rate to 2 bpm, 1400 psi after 5849 strokes. Reduce rate to 1 bpm, 1549 psi after 6106 strokes. Bump plug on calculated number of strokes (6570 sks), 1990 psi. Increase pressure 500 psi to 2500 psi. Hold 2500 psi for 5 minutes and bleed pressure. -Floats holding. Cement in place at 2:08 A.M. RUNPRD Pressure test casin to 4000 si and chart for 30 minutes. -Pressure bled off 50 psi in first 15 minutes, 25 psi second 15 minutes: Good test. RUNPRD Rig down cement head. Back out landing joint. Install FMC pack off and run in lock down screws. -Torque lock down screws to 350 ft-Ibs. Pressure test FMC packoff metal to metal seal to 5000 psi for 15 minutes: Good test. RUNPRD h n e out 7" casin rams to 3.5"x6" variable rams. Pressure test the rams with 4" and 3.5" test joints to 250 psi low, 4000 psi high. SIMOPS: -Inject down 7"x9-5/8" annulus (required 3500 psi to inject). Pump 155 bbls of LSND drilling mud at 3500 psi to keep OA Printetl: 12/30/2008 12::19:14 PM ~ ~ BP EXPLORATION Page 11 of 15 Operations Summary Report Legal Well Name: W-218 Common Well Name: W-218 Spud Date: 11/25/2008 Event Name: DRILL+COMPLETE Start: 11/24/2008 End: 12/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/14/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code ~ NPT Phase ~ Description of Operations 12/9/2008 05:30 - 13:00 7.50 WHSUR P RUNPRD open. -Ria up little red and infect 109 bbls of dead crude down OA to 13:00 - 16:00 3.00 PERFO P 16:00 - 17:30 1.50 PERFO P 17:30 - 19:00 1.50 PERFO P 19:00 - 21:30 2.50 PERFO N 21:30 - 00:00 I 2.501 PERFOBI P 12/10/2008 00:00 - 04:00 4.00 PERFO P 04:00 - 08:00 4.00 PERFO P 08:00 - 09:00 1.00 PERFO P 09:00 - 09:30 0.501 PERFOB~ P 09:30 - 10:00 I 0.501 PERFOBI P 10:00 - 14:30 ~ 4.50 ~ PERFOB~ P OTHCMP PJSM. Make up 4.5", 5 spf, 4505 Power Jet perforation guns. OTHCMP RIH with perforation guns on 4" drill pipe to 1100' MD. -Test MWD (Gamma) with 254 GPM, 378 psi. OTHCMP Slip and cut 76' of drilling line. Service the top drive. WAIT OTHCMP BP security announced that we would go to phase 3 weather conditions at 9:00 P.M. All personel should convoy to locations and stay off roads. Shut down rig to prevent an injury without ability to get to medic. OTHCMP BP security continuing to announce Phase II Level II weather conditions with expectation of phase III soon to come. -40 MPH wind with limited visibility Decision made to continue to RIH with perforation guns until Phase III condition is confirmed. -CH2MHILL drivers not driving due to road conditions, (so guns will not be fired in case losses occur) OTHCMP RIH with rforati n uns a t MD. OTHCMP Bring on pumps and wait for signal from MWD tool. Trouble shoot bad signals from MWD, adjusting pump rates to get a good signal. Begin logging from 9980' up to 9650' MD (bring MWD tool above RA tag in 7" casing). -250 GPM, 1033 psi. -Log at 300 ft/hr. -Re-log interval as needed to correlate to drilling log. OTHCMP Place guns on depth. PJSM with BP WSL, Nabors, and SLB pert specialists. Practice firing sequence. Fire the 4.5". 5 spf, 4505 Power Jet perforation auns._ -Good indication guns fired. -Well took -5 bbls of brine. PERFORATED INTERVALS OBa Sands: 9435' to 9480' MD, 45' perforated OBc Sands: 9606' to 9650' MD, 44' perforated OBb Sands: 9710' to 9785' MD, 75' perforated OTHCM Pull out of hole to 9318' MD bringing guns above op perforation. -PU 182K, SO 78K. OTHCMP Circulate one bottoms up. -250 gpm, 1000 psi. -Well took -12 bbls of brine. OTHCMP Monitor Well: Losin -1 bbl/hr Brine weight 9.0 ppg. Yflflt80: 7Z/JU/ZUUif IZ:Jtl:14 rrvl BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: W-218 Common Well Name: W-218 Spud Date: 11/25/2008 Event Name: DRILL+COMPLETE Start: 11/24/2008 End: 12/14/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2008 Rig Name: NABORS 9ES Rig Number: Date From - To Hours I Task Code NPT Phase Description of Operations 12/10/2008 10:00 - 14:30 4.50 PERFO P OTHCMP 14:30 - 19:00 4.50 PERFO P OTHCMP 19:00 - 19:30 0.50 EVAL P OTHCMP 19:30 - 21:30 2.00 EVAL P OTHCMP 21:30 - 22:30 1.00 EVAL P OTHCMP 22:30 - 00:00 1.50 EVAL P OTHCMP 12/11/2008 00:00 - 03:00 3.00 EVAL P OTHCMP ~I 03:00 - 08:00 5.00 EVAL P OTHCMP 08:00 - 16:00 8.00 EVAL P OTHCMP 16:00 - 16:30 0.50 EVAL P OTHCMP 16:30 - 17:00 0.50 EVAL P OTHCMP 17:00 - 18:00 1.00 EVAL P OTHCMP 18:00 - 22:00 4.00 EVAL P OTHCMP 22:00 - 00:00 2.00 EVAL P OTHCMP 12/12/2008 00:00 - 16:00 16.00 EVAL P OTHCMP Pull out of hole racking back 4" drill pipe to 428' MD. Lay down MWD tool and bumper sub. PJSM for laying down pert guns. Lay down fired perforation guns and blanks. -Confirm All shots fired. -Clean and clear the rig floor. -Remove SLB's tools from rig floor. Bring cleanout BHA componets to rig floor. Change out the saver sub valve on the top drive and service the crown. Make up cleanout BHA to include: -Full gauge flat bottom mill, 2 junk baskets, float, string mill, magnet, and jars. RIH with cleanout BHA to 1400' MD. Total losses to perforations for the day: 43 bbls. Continue to RIH with cleanout BHA and tag Float Collar at 9985' MD. Pick up off bottom 30' and mark with a "No-go" line. Circulate bottoms up. -550 GPM, 80 RPM, 8-10K Tq, 3350 psi, reciprocate pipe. -Stay a minimum of 30' from bottom. -PU 168K, SO 65K, ROT 83K. Pump a high vis sweep and circulate bottoms up. Pump out of hole to top pert at 9435' MD. Circulate another bottoms up while rotating and working pipe. Wash/Ream back down to 9815' MD. Pump another high vis sweep while rotating and working pipe. Pull out of hole laying down 4" drill pipe singles to 62'. Lay down Jars, magnet, string mill, boot baskets, and flat bottom mill. -Minimal erf debris in boot baskets -1 cu -More debris on magnets than in baskets. Clear floor of cleanout BHA. PJSM with SLB E-line crew and rig crew. Rig up SLB sheaves and SLB E-line unit. -Make up 6.05" gauge ring and junk basket. RIH with SLB 'unk basket/ au a rin to 9978' MD. POH with junk baskeUgauge ring. -Minimal amount of erf de ri i (-1 cup) mostly soft mushy material, but some very small metal fragments. PJSM to make u USIT tools. -RIH with USIT to log cement behind 7" casing and verify perforation intervals. SIMOPS: Safety Stand Down with crew coming on tour concerning most recent hand injury that occurred on another GPB rig. Discussed "staying in the moment", good communication, and making sure people understand the proper technique to complete the job they are doing (If not, stop the job). RIH to 2450' MD with USIT logging tool on E-line. -Cannot aet tools vast 2450' after multiple attempts Nnnted: i~~uizuus izsa:w rm • ~ BP EXPLORATION Page 13 of 15 Operations Summary Report Legal Well Name: W-218 Common Well Name: W-218 Spud Date: 11/25/2008 Event Name: DRILL+COMPLETE Start: 11/24/2008 End: 12/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/14/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/12/2008 00:00 - 16:00 16.00 EVAL P OTHCMP POH to remove two centralizers from logging tools -RIH with USIT logging tools making it to 3200' MD. -Unable to et ast 3200' MD. POH to remove another centralizer from logging tools. -RIH to 9930' MD with difficulty. Loa 7" casing from 9930' MD to surface in cement evaluation 16:00 - 17:00 1.00 EVAL P OTHCMP Rig down SLB E-line and lay down logging tools. 17:00 - 18:00 1.00 BUNCO RUNCMP Pull the wear ring. Pick up the tubing hanger and make a dummy run. 18:00 - 20:00 2.00 BUNCO RUNCMP Rlg up to run 3.5", 9.2 Ib/ft, L-80, TC-II completion. -Bring SLB I-wire spooling unit to rig floor. -Rig up Sheaves. -Bring power tongs and associated torque turn equipment to rig floor. 20:00 - 21:00 1.00 BUNCO RUNCMP PJSM with SLB, Halliburton, WSL, and rig crew. RIH with 3.5" W-LEG and XN landing nipple assembly. 21:00 - 22:30 1.50 BUNCO SFAL RUNCMP Torque turn equipment malfunction. -Trouble shoot torque turn tools. -Tongs are making up connection to optimal torque (2316 ft-Ibs), however, after the hydraulic lever is released the gauge on the tongs flashes 3200 ft-Ibs momentarily. This is showing upon the torque turn computer read out. 22:30 - 23:20 0.83 BUNCO RUNCMP Make up remaining tubing tail assembly with confidence that connections are only being made up to 2316 ft-Ibs but showing error on torque turn computer read out up to first packer assembly. -Bakerlok each connection. -Allow SLB to install and splice I-wire on first packer while swapping out all torque turn hydraulic lines, valves, electrical lines, and computer. 23:20 - 00:00 0.67 BUNCO RUNCMP Continue to RIH with 3.5", 9.2 Ib/ft, L-80, TC-II multi-packer completion with pressure guages and single i-wire. -Bakerlok all connections below packer. -Torque turn all connections to 2316 ft-Ibs. 12/13/2008 00:00 - 00:00 24.00 12/14/2008 00:00 - 00:30 0.50 RU 00:30 - 01:00 0.50 RU Total losses over 24 hrs: 8 bbls of 9.0 opg brine. RUNCMP Continue to RIH with 3.5", 9.2#, L-80, TC-II completion to 9344' MD. -Splice I-wire at the three packers and test to 5000 psi for 5 minutes. -Run 1 clamp on each joint for first 10 joints above packer. -Run 1 clamp every other joint to surface. -Torque turn each connection to 2316 ft-Ibs (optimal). -Use Jet Lube Seal Guard on all TC-II connections. -PU 100K, SO 60K. -No losses to formation. RUNCMP Continue to RIH with 3.5" tubing. Pick up joint #304 and place tubing on depth at 9892' MD. -Ran a total of 167 full clamps and 17 half clamps for i-wire. RUNCMP PJSM with SLB and rig crew. Rig us Schlumberger's E-line unit for a GR/CCL log Printed: 12/30/2008 72:39:14 PM BP EXPLORATION Page 14 of 15 Operations Summary Report Legal Well Name: W-218 Common Well Name: W-218 Spud Date: 11/25/2008 Event Name: DRILL+COMPLETE Start: 11/24/2008 End: 12/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/14/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours ' Task Code NPT Phase Description of Operations - 12/14/2008 00:30 - 01:00 0.50 BUNCO - RUNCMP -Spot E-line Unit.. -Rig up Sheaves. -Bring tools to the floor and make up. 01:00 - 05:00 4.00 BUNCO RUNCMP Lo 3.5" tubin with GR/CCL from 9840' to 9139' MD -Verif ackers are s aced out correct) between erforation intervals. POH with logging tools. 04:00 - 06:30 2.50 BUNCO RUNCMP Lay down joint #304 and #303. Space out 3.5", 9.2#, L-80, TCII completion with a 9.80' pup to place packers on depth. Pick up joint #303 and tubing hanger assembly. Terminate i-wire through the tubing hanger and test. Land 3.5" tubing on hanger. Run in lock down screws. Rig down torque turn equipment and tongs. Clear the rig floor. 06:30 - 07:00 0.50 BUNCO RUNCMP Drop the 1-5/16" ball and rod w/ rollers down to the RHC-M I ug. Lay down the landing joint. 07:00 - 09:00 2.00 BUNCO RUNCMP Pressure up the tubing to 4000 psi and chart for 30 minutes to_ r h t -Pressure bled off 75 psi in first 15 minutes, 0 psi in second 15 minutes: Good test. Bleed tubing pressure to 2500 psi and hold. Brin 3.5" x 7" annulus ressure to 4000 si and chart for 30 minutes. -Bled off 25 psi in first 15 minutes, 0 psi in second 15 minutes: Good test. Bleed annulus pressure to 0 psi followed by tubing pressure to 0 psi. Pressure annulus back up to 2800 psi to shear the DCR valve in the top GLM. Pump down both ways at 3 bpm to confirm shear. -500 psi down annulus, 530 psi down tubing. 09:00 - 09:30 0.50 WHSUR P RUNCMP Install TWC and test from below to 1000 psi. 09:30 - 12:00 2.50 BOPSU P RUNCMP Nipple down BOP's. -Remove mouse hole. -Nipple down riser and stack. 12:00 - 14:30 2.50 WHSUR P RUNCMP Install i-wire through adaptor flange and test. Nipple up adaptor flange and test to 5000 psi: Good test. Nipple up the tree and test to 5000 psi with diesel: Good test. 14:30 - 16:00 1.50 WHSUR P RUNCMP Riq up Drill Site Maintenance lubricator and test to 1000 psi.,. Pull TWC. 16:00 - 20:30 4.50 WHSUR P RUNCMP Reverse circulate 162 bbls of 9.0 ppg corrosion inhibited brine down the 3.5" x 7" annulus. -130 gpm, 350 psi. Rig up Little Red Hot Oil. -Test lines to 3000 psi. -Pump 113 bbls of 80 degree diesel freeze protect down the 3.5" x 7" annulus at 1.7 bpm, 425 psi final circulating pressure. 20:30 - 22:30 2.00 WHSUR P RUNCMP U-tube diesel freeze protect from I.A. to tubing. Rig down lines. Set back pressure valve with DSM lubricator. Printetl: 12/30/2008 12:39:14 PM ~1 BP EXPLORATION Page 15 of 15 Operations Summary Report Legal Well Name: W-218 Common Well Name: W-218 Spud Date: 11/25/2008 Event Name: DRILL+COMPLETE Start: 11/24/2008 End: 12/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/14/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/14/2008 20:30 - 22:30 2.00 WHSUR P RUNCMP -Test to 1000 psi from below. 22:30 - 00:00 1.50 WHSUR P RUNCMP Remove second annulus valves. Install 3 VR plugs. Secure cellar for rig move. Release rig from W-2181 ~ 00:00 hrs (midnight on Sunday 12/14/2008) rnntea: iu~uizuuu izsaaa rrn r ~. ; - W-218 Survey Report Report Date: December 8, 2008 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 11.350° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: W-PAD / W-218 TVD Reference Datum: Rotary Table Well; W-218 TVD Reference Elevation: 81.7 ft relative to MSL Borehole: W-218 Sea Bed /Ground Level Elevation: 53.000 ft relative to MSL UWI/API#: 500292340300 Magnetic Declination: 22.757° Survey Name /Date: W-218 /November 30, 2008 Total Field Strength: 57675.926 nT Tort /AHD / DDI / ERD ratio: 165.074° / 7758.33 ft 16.381 / 1.446 Magnetic Dip: 80.870° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: November 25, 2008 Location Lat/Long: N 70.29950252, W 149.09252397 Magnetic Declination Model: BGGM 2008 Location Grid NIE Y/X: N 5959940.770 ftUS, E 612048.920 ftUS North Reference: True North Grid Convergence Angle: +0.85436743°• Total Corr Mag North -> True North: +22.757° Grid Scale Factor: 0.99991426 Local Coordinates Referenced To: Well Head. Comments Measured Inclination Azimuth SulrSea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 00 ft ftUS ftUS Fill t).t)t) V.VV V.VV -t31. /V V.VV V.VU V.VU U.UU V.VV V.UU U.VV .7.7.7YY4V.// VILV4O..7L IV /V. L.7.7JVGUL VV I4.`7. VtlGJLJ.'1/ GYD GC SS 90.00 0.31 72.51 8. 30 90.00 0.12 0.24 0.24 0.07 0.23 0.34 5959940. 85 612049.15 N 70. 29950272 W 149. 09252209 179.00 0.76 292.61 97. 30 179.00 0.35 0.80 0.38 0.37 -0.08 1.14 5959941. 14 612048.83 N 70. 29950354 W 149. 09252464 278.00 3.15 288.67 196. 23 277.93 0.82 4.18 3.59 1.50 -3.27 2.42 5959942. 22 612045.63 N 70. 29950661 W 149. 09255042 369.00 3.40 293.57 287. 08 368.78 1.71 9.37 8.78 3.38 -8.11 0.41 5959944. 02 612040.76 N 70. 29951174 W 149. 09258963 459.00 3.28 335.10 376. 94 458.64 4.36 14.39 13.47 6.78 -11.64 2.63 5959947. 37 612037.18 N 70. 29952104 W 149. 09261822 553.00 4.45 8.07 470. 74 552.44 10.17 20.56 17.74 12.83 -12.26 2.62 5959953. 41 612036.47 N 70. 29953757 W 149. 09262325 646.00 6.19 10.01 563. 34 645.04 18.78 29.18 23.95 21.34 -10.88 1.88 5959961. 94 612037.72 N 70. 29956082 W 149. 09261209 MWD+IFR+MS 671.81 6.21 11.06 588 .99 670.69 21.57 31.97 26.22 24.08 -10.37 0.45 5959964. 69 612038.19 N 70. 29956831 W 149. 09260796 762.81 6.22 357.56 679 .46 761.16 31.28 41.78 35.18 33.84 -9.64 1.60 5959974. 46 612038.78 N 70. 29959496 W 149. 09260201 856.13 7.11 359.30 772 .15 853.85 41.84 52.61 45.75 44.66 -9.92 0.98 5959985. 28 612038.33 N 70 .29962454 W 149. 09260 951.79 8.20 1.64 866 .96 948.66 54.35 65.35 58.23 57.40 -9.80 1.18 5959998. 01 612038.27 N 70 .29965934 W 149. 09260 1047.60 10.60 3.50 961 .48 1043.18 69.82 80.99 73.59 73.03 -9.07 2.52 5960013. 65 612038.77 N 70 .29970203 W 149. 092597 1140.15 13.78 4.67 1051 .93 1133.63 89.20 100.53 92.83 92.52 -7.65 3.45 5960033. 15 612039.89 N 70 .29975527 W 149. 09258591 1234.74 18.51 3.84 1142 .76 1224.46 115.29 126.83 118.88 118.74 -5.73 5.01 5960059. 40 612041.43 N 70 .29982691 W 149. 09257033 1327.29 22.58 1.60 1229 .41 1311.11 147.38 159.30 151.23 151.17 -4.24 4.48 5960091. 85 612042.42 N 70 .29991552 W 149. 09255834 1423.24 24.71 1.07 1317 .30 1399.00 185.27 197.78 189.67 189.64 -3.36 2.23 5960130. 33 612042.74 N 70 .30002061 W 149. 09255115 1517.42 26.09 3.59 1402 .37 1484.07 225.17 238.17 230.00 230.00 -1.69 1.86 5960170. 70 612043.80 N 70 .30013086 W 149. 09253767 1612.35 27.18 3.18 1487 .23 1568.93 267.31 280.72 272.48 272.48 0.82 1.16 5960213. 21 612045.68 N 70 .30024692 W 149. 09251734 1706.28 29.15 3.85 1570 .03 1651.73 311.23 325.06 316.75 316.73 3.54 2.12 5960257. 49 612047.74 N 70 .30036780 W 149. 09249526 1799.69 31.49 4.00 1650 .66 1732.36 357.99 372.21 363.83 363.77 6.77 2.51 5960304. 57 612050.27 N 70 .30049632 W 149. 09246911 1895.01 34.56 4.77 1730 .57 1812.27 409.55 424.15 415.70 415.56 10.76 3.25 5960356. 41 612053.48 N 70 .30063780 W 149. 09243683 1988.04 41.12 4.84 1804 .00 1885.70 466.22 481.19 472.65 472.40 15.54 7.05 5960413 .31 612057.41 N 70 .30079308 W 149. 09239811 SurveyEditor Ver SP 2.1 Bld( doc4Ox_1OO) W-218\W-218 drilling\W-218 drilling\W-218 Generated 1/12/2009 3:33 PM Page 1 of 4 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft it de 100ft ftUS ftUS "LU23:S.UU 44.'LS 4.i5b lt$/:S.iSV 1`.1J.7.JV J3V.I[5 J40.J0 J30.`JJ J30..74 LV..70 3.JV J~OV4//.JL OILV01..7V IV /V.JVV.700J1 VV 14.7. V.7GJa4V4 2177.94 48.31 4.85 1939.40 2021.10 598.34 614.16 605.49 604.89 26.79 4.28 5960545. 94 612066.69 N 70.30115505 W 149. 09230702 2272.33 53.90 4.82 1998.64 2080.34 671.30 687.60 678.87 678.07 32.98 5.92 5960619. 20 612071.78 N 70.30135495 W 149. 09225689 2364.78 57.64 5.67 2050.64 2132.34 747.29 764.02 755.23 754.17 39.98 4.12 5960695. 38 612077.64 N 70.30156285 W 149. 09220021 2461.48 62.66 5.67 2098.75 2180.45 830.72 847.87 838.99 837.60 48.26 5.19 5960778. 93 612084.68 N 70.30179079 W 149. 09213312 2556.40 64.75 5.94 2140.80 2222.50 915.41 932.96 924.01 922.26 56.87 2.22 5960863. 69 612092.03 N 70.30202206 W 149. 09206340 2652.41 65.79 5.52 2180.96 2262.66 1002.20 1020.16 1011.16 1009.03 65.57 1.15 5960950. 57 612099.44 N 70.30225911 W 149. 09199289 2748.39 66.01 4.93 2220.16 2301.86 1089.31 1107.78 1098.74 1096.28 73.55 0.61 5961037. 92 612106.11 N 70.30249746 W 149. 09192827 2842.17 65.55 4.75 2258.63 2340.33 1174.29 1193.30 1184.25 1181.50 80.77 0.52 5961123. 24 612112.06 N 70.30273028 W 149. 09186981 2936.85 64.94 5.05 2298.27 2379.97 1259.72 1279.28 1270.22 1267.16 88.11 0.71 5961208. 99 612118.12 N 70.30296431 W 149. 09181033 3031.85 64.48 4.74 2338.86 2420.56 1345.07 1365.18 1356.11 1352.74 95.44 0.57 5961294. 67 612124.17 N 70.30319811 W 149. 0917 3124.74 63.93 4.91 2379.28 2460.98 1428.16 1448.81 1439.73 1436.08 102.48 0.61 5961378. 09 612129.96 N 70.30342578 W 149. 5 0916 3219.40 65.42 4.70 2419.77 2501.47 1513.16 1534.37 1525.29 1521.34 109.64 1.59 5961463 .44 612135.86 N 70.30365870 W 149. 09163592 3313.28 64.53 4.03 2459.48 2541.18 1597.60 1619.44 1610.35 1606.16 116.12 1.15 5961548 .34 612141.07 N 70.30389042 W 149. 09158346 3407.08 65.20 4.87 2499.32 2581.02 1681.90 1704.35 1695.27 1690.82 122.71 1.08 5961633 .08 612146.39 N 70.30412171 W 149. 09153007 3500.90 64.40 4.36 2539.27 2620.97 1766.20 1789.24 1780.15 1775.43 129.54 0.98 5961717 .78 612151.96 N 70.30435286 W 149. 09147472 3595.03 65.39 4.40 2579.21 2660.91 1850.81 1874.48 1865.39 1860.42 136.05 1.05 5961802 .85 612157.20 N 70.30458504 W 149. 09142198 3688.02 65.33 3.99 2617.98 2699.68 1934.68 1959.00 1949.91 1944.72 142.23 0.41 5961887 .22 612162.13 N 70.30481533 W 149. 09137189 3783.44 65.74 5.72 2657.50 2739.20 2020.97 2045.85 2036.75 2031.25 149.59 1.71 5961973 .85 612168.19 N 70.30505174 W 149. 09131232 3876.64 65.32 5.40 2696.10 2777.80 2105.36 2130.68 2121.56 2115.68 157.80 0.55 5962058 .38 612175.15 N 70.30528240 W 149. 09124573 3969.99 65.39 7.07 2735.03 2816.73 2189.87 2215.53 2206.35 2200.02 167.02 1.63 5962142 .85 612183.10 N 70.30551281 W 149. 09117107 4064.89 64.50 7.31 2775.22 2856.92 2275.61 2301.50 2292.22 2285.32 177.78 0.97 5962228 .28 612192.59 N 70.30574582 W 149 .09108390 4159.45 65.77 7.94 2814.98 2896.68 2361.22 2387.29 2377.89 2370.35 189.16 1.47 5962313 .47 612202.71 N 70.30597813 W 149 .09099166 4253.42 65.66 7.62 2853.63 2935.33 2446.71 2472.94 2463.41 2455.22 200.76 0.33 5962398 .49 612213.03 N 70.30620997 W 149 .09089771 4347.98 65.04 7.52 2893.06 2974.76 2532.46 2558.89 2549.25 2540.41 212.08 0.66 5962483 .84 612223.08 N 70.30644271 W 149 .09080598 4442.49 65.80 7.66 2932.38 3014.08 2618.23 2644.83 2635.09 2625.60 223.43 0.82 5962569 .18 612233.16 N 70.30667545 W 149 .09071400 4537.09 65.60 7.45 2971.31 3053.01 2704.25 2731.05 2721.22 2711.07 234.77 0.29 5962654 .80 612243.22 N 70.30690895 W 149 .09062215 4632.12 65.86 9.69 3010.37 3092.07 2790.78 2817.68 2807.67 2796.73 247.68 2.17 5962740 .63 612254.85 N 70.30714295 W 149 .09051754 4725.23 67,25 13.72 3047.43 3129.13 2876.17 2903.09 2892.51 2880.35 265.02 4.24 5962824 .49 612270.94 N 70.30737139 W 149 .09037 4819.56 67.48 18.13 3083.75 3165.45 2962.93 2990.15 2978.09 2964.04 288.90 4.32 5962908 .53 612293.57 N 70.30760004 W 149 .09018 4914.46 65.47 19.21 3121.63 3203.33 3049.23 3077.16 3062.89 3046.47 316.75 2.36 5962991 .36 612320.19 N 70.30782523 W 149 .08995793 5009.12 65.41 19.61 3160.97 3242.67 3134.47 3163.26 3146.68 3127.67 345.36 0.39 5963072 .97 612347.58 N 70.30804706 W 149 .08972611 5103.04 67.01 19.66 3198.86 3280.56 3219.51 3249.19 3230.36 3208.61 374.24 1.70 5963154 .32 612375.25 N 70.30826818 W 149 .08949213 5197.87 67.32 20.03 3235.66 3317.36 3305.95 3336.59 3315.52 3290.82 403.91 0.49 5963236 .96 612403.68 N 70.30849276 W 149 .08925173 5292.51 67.35 19.71 3272.13 3353.83 3392.32 3423.92 3400.71 3372.95 433.59 0.31 5963319 .52 612432.14 N 70.30871713 W 149 .08901122 5387.76 67.41 19.94 3308.76 3390.46 3479.28 3511.84 3486.60 3455.66 463.41 0.23 5963402 .66 612460.72 N 70.30894309 W 149 .08876961 9-5/8" C~ 5461'md 5486.45 66.67 20.04 3347.26 3428.96 3569.12 3602.72 3575.42 3541.06 494.48 0.76 5963488 .50 612490.50 N 70.30917638 W 149 .08851789 5582.00 67.32 20.14 3384.60 3466.30 3656.05 3690.67 3661.45 3623.66 524.69 0.69 5963571 .53 612519.47 N 70.30940203 W 149 .08827308 5677.90 68.16 21.10 3420.93 3502.63 3743.64 3779.42 3748.18 3706.72 555.94 1.27 5963655 .05 612549.49 N 70.30962894 W 149 .08801979 5773.44 66.48 20.32 3457.77 3539.47 3830.62 3867.57 3834.39 3789.17 587.12 1.91 5963737 .94 612579.43 N 70.30985419 W 149 .08776716 5868.41 66.21 21.30 3495.87 3577.57 3916.42 3954.56 3919.52 3870.49 618.02 0.99 5963819 .70 612609.11 N 70.31007632 W 149 .08751672 SurveyEditor Ver SP 2.1 Bld( doc40x_100) W-218\W-218 drilling\W-218 drilling\W-218 Generated 1/12/2009 3:33 PM Page 2 of 4 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure tt de de ft ft n tt tt ft ft de ott tt itUS ftUS 5964A8 65.9a 21.ti1 a534. 6t5 3b16.:ii1 4VVZ.4y 4V4Z.UV 4VV4. `J4 3`Jb i.az o~u.i~ uo/ oao3au i.oV oim4u. uc rv /U. 31UCy0al vv 14y.U0/GOOJ/ 6059.47 67.50 22.36 3572. 39 3654.09 4088.57 4129.62 4090. 45 4033.01 683.09 1.73 5963983.16 612671. 75 N 70. 31052030 W 149. 08698939 6155.01 66.96 22.13 3609. 36 3691.06 4175.08 4217.71 4176. 45 4114.54 716.44 0.61 5964065.18 612703. 88 N 70. 31074304 W 149. 08671912 6250.42 66.48 23.43 3647. 07 3728.77 4260.98 4305.36 4261. 93 4195.35 750.38 1.35 5964146.47 612736. 60 N 70. 31096378 W 149. 08644413 6346.30 67.95 24.23 3684. 20 3765.90 4347.28 4393.75 4347. 86 4276.21 786.09 1.72 5964227.85 612771. 10 N 70. 31118467 W 149. 08615467 6442.18 68.39 23.42 3719. 86 3801.56 4434.18 4482.75 4434. 48 4357.63 822.04 0.91 5964309.78 612805. 83 N 70. 31140709 W 149. 08586330 6537.83 67.41 24.11 3755. 84 3837.54 4520.73 4571.38 4520. 85 4438.73 857.76 1.22 5964391.41 612840. 33 N 70. 31162865 W 149. 08557388 6633.61 67.18 24.24 3792. 81 3874.51 4606.89 4659.73 4606. 90 4519.34 893.94 0.27 5964472.54 612875. 30 N 70. 31184886 W 149. 08528061 6715.37 69.09 22.70 3823. 26 3904.96 4681.07 4735.61 4681. 07 4588.94 924.15 2.92 5964542.57 612904. 47 N 70. 31203898 W 149. 08503575 . 6824.45 67.73 21.66 3863. 40 3945.10 4780.68 4837.03 4780. 73 4682.85 962.44 1.53 5964637.04 612941. 35 N 70. 31229554 W 149. 08472537 6920.26 67.24 22.14 3900. 09 3981.79 4867.69 4925.54 4867. 84 4764.97 995.46 0.69 5964719.64 612973. 13 N 70. 31251987 W 149. 08445 7015.91 68.77 22.12 3935. 91 4017.61 4954.82 5014.22 4955. 12 4847.13 1028.86 1.60 5964802.27 613005. 31 N 70. 31274430 W 149. 08418 7111.41 68.00 21.92 3971. 09 4052.79 5042.06 5103.01 5042. 57 4929.43 1062.15 0.83 5964885.06 613037. 37 N 70. 31296914 W 149. 08391716 7207.58 67.36 21.65 4007. 61 4089.31 5129.56 5191.97 5130. 30 5012.04 1095.17 0.71 5964968.15 613069. 14 N 70. 31319481 W 149. 08364952 7303.14 68.04 21.82 4043. 87 4125.57 5216.52 5280.39 5217. 54 5094.17 1127.91 0.73 5965050.74 613100. 65 N 70. 31341916 W 149. 08338411 7397.55 67.73 21.57 4079. 41 4161.11 5302.56 5367.85 5303. 90 5175.44 1160.24 0.41 5965132.48 613131. 77 N 70. 31364117 W 149. 08312201 7492.89 66.70 20.65 4116. 34 4198.04 5389.19 5455.75 5390. 85 5257.44 1191.90 1.40 5965214.93 613162 .20 N 70 .31386516 W 149. 08286535 7589.03 67.47 21.13 4153 .77 4235.47 5476.52 5544.30 5478. 53 5340.17 1223.48 0.92 5965298.12 613192 .54 N 70 .31409116 W 149. 08260936 7684.70 68.59 21.18 4189 .56 4271.26 5563.94 5633.02 5566. 35 5422.91 1255.50 1.17 5965381.32 613223 .31 N 70 .31431719 W 149. 08234978 7780.09 68.56 21.49 4224 .41 4306.11 5651.39 5721.82 5654. 23 5505.62 1287.80 0.30 5965464.50 613254 .38 N 70 .31454314 W 149. 08208786 7876.37 67.66 21.32 4260 .30 4342.00 5739.36 5811.16 5742. 66 5588.80 1320.41 0.95 5965548.14 613285 .74 N 70 .31477036 W 149. 08182352 7968.80 69.55 21.14 4294 .02 4375.72 5824.14 5897.21 5827. 90 5669.01 1351.57 2.05 5965628.81 613315 .70 N 70 .31498948 W 149. 08157087 8067.31 67.33 18.32 4330 .22 4411.92 5914.76 5988.82 5918. 95 5755.23 1382.51 3.49 5965715.47 613345 .35 N 70 .31522501 W 149. 08132001 8162.55 66.17 14.76 4367 .83 4449.53 6001.88 6076.32 6006. 32 5839.09 1407.43 3.64 5965799.69 613369 .01 N 70 .31545410 W 149. 08111795 8258.28 65.37 9.87 4407 .14 4488.84 6089.13 6163.61 6093. 56 5924.34 1426.05 4.73 5965885.20 613386 .36 N 70 .31568699 W 149. 08096690 8353.89 64.82 8.29 4447 .40 4529.10 6175.78 6250.33 6180. 02 6009.97 1439.74 1.61 5965971.01 613398 .76 N 70 .31592091 W 149. 08085584 8449.93 63.65 5.71 4489 .15 4570.85 6262.01 6336.81 6265 .95 6095.81 1450.29 2.71 5966056.99 613408 .03 N 70 .31615539 W 149. 08077021 8545.25 63.17 1.47 4531 .83 4613.53 6346.44 6422.05 6349 .94 6180.85 1455.63 4.01 5966142.09 613412 .10 N 70 .31638772 W 149. 08072678 8639.26 62.81 1.21 4574 .53 4656.23 6428.92 6505.80 6431 .92 6264.58 1457.59 0.46 5966225.84 613412 .81 N 70 .31661647 W 149. 08071 8735.84 63.24 0.96 4618 .34 4700.04 6513.62 6591.87 6516 .13 6350.64 1459.22 0.50 5966311.90 613413 .16 N 70 .31685157 W 149. 08069 8831.42 62.94 0.83 4661 .59 4743.29 6597.43 6677.10 6599 .51 6435.86 1460.55 0.34 5966397.13 613413 .22 N 70 .31708438 W 149. 08068650 8926.71 63.37 0.66 4704 .63 4786.33 6681.00 6762.12 6682 .68 6520.87 1461.65 0.48 5966482.14 613413 .06 N 70 .31731663 W 149. 08067741 9021.35 60.92 1.25 4748 .84 4830.54 6763.29 6845.79 6764 .64 6604.53 1463.04 2.65 5966565.80 613413 .20 N 70 .31754517 W 149 .08066602 9117.98 60.81 0.51 4795 .89 4877.59 6846.29 6930.20 6847 .33 6688.92 1464.34 0.68 5966650.19 613413 .24 N 70 .31777573 W 149 .08065537 9213.25 60.56 0.79 4842 .53 4924,23 6927.92 7013.27 6928 .70 6771.99 1465.28 0.37 5966733.26 613412 .94 N 70 .31800265 W 149 .08064760 9308.38 60.52 0.29 4889 .32 4971.02 700928 7096.09 7009 .83 6854.81 1466.06 0.46 5966816.08 613412 .49 N 70 .31822892 W 149 .08064114 9404.24 60.87 0.30 4936 .24 5017.94 7091.32 7179.69 7091 .69 6938.40 1466.49 0.37 5966899.66 613411 .67 N 70 .31845729 W 149 .08063752 9499.72 61.52 0.62 4982 .24 5063.94 7173.48 7263.35 7173 .70 7022.06 1467.17 0.74 5966983.31 613411 .10 N 70 .31868585 W 149 .08063194 9594.95 58.85 2.89 5029.59 5111.29 7254.93 7345.97 7255 .05 7104.64 1469.67 3.48 5967065.91 613412 .37 N 70 .31891142 W 149 .08061148 9690.75 57.66 2.75 5080 .00 5161.70 7335.49 7427.43 7335 .56 7186.00 1473.68 1.25 5967147.32 613415 .17 N 70 .31913371 W 149 .08057885 9786.81 58.29 2.90 5130.94 5212.64 7416.03 7508.87 7416 .06 7267.35 1477.70 0.67 5967228.70 613417 .97 N 70 .31935593 W 149 .08054618 SurveyEditor Ver SP 2.1 Bld( doc40x_100) W-218\W-218 drilling\W-218 drilling\W-218 Generated 1/12/2009 3:33 PM Page 3 of 4 Comments Measured Inclination Azimuth Sub-Sea TVD Typ Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de OOft ftUS ftUS 9882.61 58.33 2.70 5181.26 5262.96 7496.64 7590.39 7496.65 7348.76 1481.68 0.18 5967310.16 9977.83 58.44 2.81 5231.18 5312.88 7576.82 7671.48 7576.82 7429.76 1485.58 0.15 5967391.20 Last Survey 10020.77 58.16 2.66 5253.74 5335.44 7612.94 7708.01 7612.95 7466.25 1487.32 0.72 5967427.71 TD (Projected) 10080.00 58.16 2.66 5284.99 5366.69 7662.68 7758.33 7662.71 7516.51 1489.65 0.00 5967478.00 Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata -gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD + IFR + MS - (In-field referenced MWD with mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) IftUSI Easting (Xi fftUSl Surface : 4963 FSL 1175 FEL S21 T11 N R12E UM 5959940.77 612048.92 BHL : 1920 FSL 4948 FEL S10 T11 N R12E UM 5967478.00 613426.21 613420.74 N 70.31957836 W 149.08051378 613423.43 N 70.31979962 W 149.08048205 613424.62 N 70.31989932 W 149.08046786 613426.21 N 70.32003663 W 149.08044885 r SurveyEditor Ver SP 2.1 Bld( doc40x_100) W-218\W-218 drilling\W-218 drilling\W-218 Generated 1/12/2009 3:33 PM Page 4 of 4 XC~GY YV C1 iNT V.. .'?CG...'?. t2. tl.l. V'. ~. ELEV = __ 55.68 ,_.,. ~W~.. pP =' _a.~ ._.. 300' ~...__. ax Angle = 69 deg atum MD = 9536 35 31um Np = 5000' SS W-218 sart~ r ~ t ~.... r~vt ~ aaa€c- ~s -ru~L i c~ I? I~IT CAIN ALSd 81=1313E1t5Bl BY PI~SSUI'~. IS4 1=1tC®43U4 PSI. TEST PFtlESSURE PKR RATING = 5415 PSI (4332 PSI fS 88~ C1F PK~2 RATINt'a)"'" 41 i2" XO 3-1 t2", IR - 2.992" 3f179' 1~3-1/2" HES X N~', IQ= 2.813" ~ 7'" CSG', 94#, A-55, Welded, ID = 19.124" ] ~ 518" CSG, 47#, L-8Q„ BTC-M, ID = 8.661 " t ~ "CSG, 26#, L-8Q, TC-~ x BT~M }C{3 , ID = 6.276"~ lUlinimum ICS = 2.75" ~ 988©' 3-112° NES XN NIPPLE GAS LIFT MANDRELS ST Mp Np pEV TYPE VLV LATCH PORT DATE 6 9317 4975 60 MMG DCR RK 0 12J13lOE WATER INJECTION MAN DRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 9415 5022 6{1 MMG-W DMY RK 0 12/13lOf 4 9505 506? F~1 MMG-W ~ RK 0 12113JOf 3 9622 5125 $ MMG-W DMY RK 0 1219 3IQf 2 9670 5150 5& MMG-W DMY RIC 0 1?J131i1E 1 9820 5230 56 MMG-W DMY RK 0 17J13I0; 3=112" HES X NIP, ID = 2.813" ~ 'CSG 26#, Marker JCJINT wlRA TAG iD = 6.276"[ HES A HR PKR w / 1 J4" FEED THRLI, ID = 2.965° ~ $~~{~' ~--~ NDPG, Single Pressure Gauge ~ 1/2" TBG, 12.6# L-80, .110&7 bpf, w! RA TAG ~ ~~' ~7" HES AR PKR w 1114" FEED THRIJ, 3 = 2.965" ...REF Lt7G: SLB Real~me LWD A NGLE A T TUP PERF; Note: Refer to Roductican Df3 for hlstnr~al perf data SCLE SPF INTERVAL OpnlScfz DATE.... 41!2" 5 aba 9435'-948(1` O 12110!08 4-117' S t7bc 960Fs`-9650' Cl 121i (7108 4-it2" 5 Obd 9710`-9785' O 12!1010$ 9547" NDPG, Single Pressure Gauge 9592' 3112" HES X NIP. ID = 2.813" '', 9699' -] 7" HES A HR PKR w 1 114" FEED THRII, ID = 2.955' ~ 9713' ~ NDPG, Single Pressure Cauge -11 `" TBG, 9:2ff, L-80, TGII, .{11187 bpf, ID = 2.992'. PBTD IT' CSG, 2611: L-S0, BTGM, ID = 6.275 ~ I 10071' 9799' 3-112'. HES X NIP, ID = 2.813" 9$49' 3-112° HES X NIP,. ID = 2.813" 9~iS4' 3-112°' HES XN N~', - 2.75" ~~~;~' 3-1l2" WLEG, ID = 2..'952" DATE REV BY COMMENTS DATE REV 8Y CON~tIEMS ORION UNfI` 12l14/U8 N9 ES ORIGINAL COMPLETION WELL: Vh~218 1?127/OS (CLH CORRECTIONS PERAAITNo: # 208174 API M1lo: 5Q-02923403 Sec 21, T11 N, 812E BP Expl4ratiarl (Alaska} ~ ~ gyrodata Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 December 10, 2008 State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: W Pad, Well #W-218 Prudhoe Bay, Alaska Enclosed, please find two (2) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, ~'~~. _. Rob Shoup North American Regional Manager RS:tf I ~ Serving the Waridwide Energy Industry with Precisit~n Survey Instrumentation • ~~® ~~ Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP W Pad #W-218 Nabors #9ES Prudhoe Bay, AK AK1108G_171 25 Nov 2008 Serving the Worldwide energy In-tust~y ~:,i'h ~reni= on S~s~~~oy ins,!rne:~in-~ion e A Gyrodata Directional Survey for BP EXPLORATION Lease: W-Pad Well: W-218, 5" Drillpipe Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK1108G 171 Run Date: 25 Nov 2008 Surveyor: Michael Villarreal Calculation Method: MINIMUM'CURVATURE _. Survey surface coordinates obtained from: Directional Drilling Company Survey Latitude: 70.299503 deg. N Longitude: 149.092524 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location BP Exploration Lease: W-Pad Well: W-218, 5" Drillpipe Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK1108G 171 A Gyrodata Directional Survey MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG VERTICAL CLOSURE SEVERITY DEPTH DIST. AZIMUTH deg./ feet feet deg. 25 ft. 0.00 0.00 0.00 N 0 0 E 0.00 0.00 0.0 0.0 0 - 646 FT. RATE GYROSCOPIC MULTISHOT SURVEY RUN INSIDE 5" DRILLPIPE ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO NABORS #9ES R.K.B. OF 81.7 FT. AMSL 90.00 0.31 72.51 N 72 31 E 0.09 90.00 179.00 0.76 292.61 N 67 23 W 0.29 179.00 278.00 3.15 288.67 N 71 20 W 0.60 277.93 369.00 3.40 293.57 N 66 26 W 0.10 368.78 459.00 3.28 335.10 N 24 54 W 0.66 458.64 553.00 4.45 .8.07 N 8 4 E 0.66 552.44 646.00 6.19 10.01 N 10 1 E 0.47 645.04 Final Station Closure: Distance:. 23.95 ft Az: 333:01 deg. 0.2 72.5 0.4 347.9 3.6 294.7 8.8 292.6 13.5 300.2 17.7 316.3 24.0 333.0 HORIZONTAL COORDINATES feet 0.00 N 0.00 E 0.07 N 0.37 N 1.50 N 3.38 N 6.78 N 12.83 N 21.34 N 0.23 E 0.08 W 3.26 W B.lOW 11.63 W 12.25 W 10.87 W Y ~' 2 SCHLUMBERGER Survey report Client .................... Field ..................... Well ...................... API number ................ Engineer .................. COUNTY :................... STATE :.................... ----- Survey calculation m Method for positions.....: Method for DLS............ BP Exploration (Alaska) Inc. Polaris W-218 05-029-23403-00 W. Nicoll NSB AK ethods------------- Minimum curvature Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference...........: Driller's Depth GL above permanent.......: 53.20 ft KB above permanent.......: NA ft DF above permanent.......: 81.70 ft -----,Vertical section origin---------------- '~ Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft Azimuth from Vsect Origin to target ?~ ~-.. [(c)2008 IDEAL ID13_OC_02] 11.35 degrees 6-Dec-2008 20:50:53 Page 1 of 5 Spud date ................. 25-Nov-08 Last survey date.........: 06-Dec-08 Total accepted surveys...: 109 MD of first survey.......: 0.00 ft MD of last survey........: 10080.00 ft ----- Geomagnetic data --- Magnetic model...........: Magnetic date ............: Magnetic field strength..: Magnetic dec (+E/W-).....: Magnetic dip .............. BGGM version 2008 25-Nov-2008 57668.16 GAMA 22.75 degrees 80.87 degrees r ~ \_J ----- MWD survey Reference Criteria --------- Reference G ............... 1002.68 meal Reference H ............... 57668.00 GAMA Reference Dip ............: 80.88 degrees Tolerance of G...........: (+/-) 2.50 meal Tolerance of H...........: (+/-)300.00 GAMA Tolerance of Dip.........: (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 22.75 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 22.75 degrees (Total az corr = magnetic dec - grid cony) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • SCHLUMBERGER Survey Report 6- Dec-2008 20:50:53 Page 2 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 1 -------- 0.00 ------ 0.00 ------- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 90.00 0.31 72.51 90.00 90.00 0.12 0.07 0.23 0.24 72.51 0.34 BP _GYD SS 3 179.00 0.76 292.61 89.00 179.00 0.35 0.37 -0.08 0.38 347.43 1.14 BP _GYD SS 4 278.00 3.15 288.67 99.00 277.93 0.82 1.50 -3.27 3.59 294.60 2.42 BP _GYD SS 5 369.00 3.40 293.57 91.00 368.78 1.71 3.38 -8.11 8.78 292.60 0.41 BP _GYD SS 6 459.00 3.28 335.10 90.00 458.64 4.36 6.78 -11.64 13.47 300.21 2.63 BP _GYD SS 7 553.00 4.45 8.07 94.00 552.44 10.17 12.83 -12.26 17.74 316.30 2.62 BP _GYD SS 8 646.00 6.19 10.01 93.00 645.04 18.78 21.34 -10.88 23.95 332.98 1.88 BP _GYD SS • 9 671.81 6.21 11.06 25.81 670.69 21.57 24.08 -10.37 26.22 336.70 0.45 BP _MWD+IFR+MS 10 762.81 6.22 357.56 91.00 761.16 31.28 33.84 -9.64 35.18 344.10 1.60 BP _MWD+IFR+MS 11 856.13 7.11 359.30 93.32 853.85 41.84 44.66 -9.92 45.75 347.47 0.98 BP _MWD+IFR+MS 12 951.79 8.20 1.64 95.66 948.66 54.35 57.40 -9.80 58.23 350.31 1.18 BP _MWD+IFR+MS 13 1047.60 10.60 3.50 95.81 1043.18 69.82 73.03 -9.07 73.59 352.92 2.52 BP _MWD+IFR+MS 14 1140.15 13.78 4.67 92.55 1133.63 89.20 92.52 -7.65 92.83 355.27 3.45 BP _MWD+IFR+MS 15 1234.74 18.51 3.84 94.59 1224.46 115.29 118.74 -5.73 118.88 357.24 5.01 BP _MWD+IFR+MS 16 1327.29 22.58 1.60 92.55 1311.11 147.38 151.17 -4.24 151.23 358.39 4.48 BP _MWD+IFR+MS 17 1423.24 24.71 1.07 95.95 1399.00 185.27 189.64 -3.36 189.67 358.99 2.23 BP _MWD+IFR+MS 18 1517.42 26.09 3.59 94.18 1484.07 225.17 230.00 -1.69 230.00 359.58 1.86 BP _MWD+IFR+MS 19 1612.35 27.18 3.18 94.93 1568.93 267.31 272.48 0.82 272.48 0.17 1.16 BP _MWD+IFR+MS 20 1706.28 29.15 3.85 93.93 1651.73 311.23 316.73 3.54 316.75 0.64 2.12 BP _MWD+IFR+MS 21 1799.69 31.49 4.00 93.41 1732.36 357.99 363.77 6.77 363.83 1.07 2.51 BP _MWD+IFR+MS 22 1895.01 34.56 4.77 95.32 1812.27 409.55 415.56 10.76 415.70 1.48 3.25 BP _MWD+IFR+MS 23 1988.04 41.12 4.84 93.03 1885.70 466.22 472.40 15.54 472.65 1.88 7.05 BP • _MWD+IFR+MS 24 2083.00 44.25 4.86 94.96 1955.50 530.18 536.54 20.98 536.95 2.24 3.30 BP _MWD+IFR+MS 25 2177.94 48.31 4.85 94.94 2021.10 598.34 604.90 26.79 605.49 2.54 4.28 BP _MWD+IFR+MS 26 2272.33 53.90 4.82 94.39 2080.34 671.30 678.07 32.98 678.87 2.78 5.92 BP _MWD+IFR+MS 27 2364.78 57.64 5.67 92.45 2132.34 747.29 754.17 39.98 755.23 3.03 4.12 BP _MWD+IFR+MS 28 2461.48 62.66 5.67 96.70 2180.45 830.72 837.60 48.26 838.99 3.30 5.19 BP _MWD+IFR+MS 29 2556.40 64.75 5.94 94.92 2222.50 915.41 922.26 56.87 924.01 3.53 2.22 BP _MWD+IFR+MS 30 2652.41 65.79 5.52 96.01 2262.66 1002.20 1009.03 65.57 1011.16 3.72 1.15 BP _MWD+IFR+MS [(c)2008 IDEAL ID13_OC_02] SCHLUMBERGER Survey Report 6-Dec-2008 20:50:53 Page 3 of 5 --- Seq -------- Measured ------ Incl ------- Azimuth ------ Course -------- TVD -------- Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 31 -------- 2748.39 ------ 66.01 ------- 4.93 ------ 95.98 -------- 2301.86 1089.31 1096.28 73.55 1098.74 3.84 0.61 BP_ MWD+IFR+MS 32 2842.17 65.55 4.75 93.78 2340.33 1174.29 1181.50 80.77 1184.25 3.91 0.52 BP_ MWD+IFR+MS 33 2936.85 64.94 5.05 94.68 2379.98 1259.72 1267.16 88.11 1270.22 3.98 0.71 BP_ MWD+IFR+MS 34 3031.85 64.48 4.74 95.00 2420.56 1345.07 1352.74 95.44 1356.11 4.04 0.57 BP_ MWD+IFR+MS 35 3124.74 63.93 4.91 92.89 2460.98 1428.16 1436.08 102.48 1439.73 4.08 0.61 BP_ MWD+IFR+MS 36 3219.40 65.42 4.70 94.66 2501.47 1513.17 1521.34 109.64 1525.29 4.12 1.59 BP_ MWD+IFR+MS 37 3313.28 64.53 4.03 93.88 2541.18 1597.60 1606.16 116.12 1610.35 4.14 1.15 BP_ M[nID+IFR+MS 38 3407.08 65.20 4.87 93.80 2581.03 1681.90 1690.82 122.71 1695.27 4.15 1.08 BP_ MWD+IFR+MS 39 3500.90 64.40 4.36 93.82 2620.97 1766.20 1775.43 129.54 1780.15 4.17 0.98 BP_ MWD+IFR+MS 40 3595.03 65.39 4.40 94.13 2660.91 1850.81 1860.42 136.05 1865.39 4.18 1.05 BP_ MWD+IFR+MS 41 3688.02 65.33 3.99 92.99 2699.68 1934.68 1944.72 142.23 1949.91 4.18 0.41 BP_ MWD+IFR+MS 42 3783.44 65.74 5.72 95.42 2739.20 2020.97 2031.25 149.59 2036.75 4.21 1.71 BP_ MWD+IFR+MS 43 3876.64 65.32 5.40 93.20 2777.80 2105.36 2115.68 157.80 2121.56 4.27 0.55 BP_ MWD+IFR+MS 44 3969.99 65.39 7.07 93.35 2816.73 2189.87 2200.02 167.02 2206.35 4.34 1.63 BP_ MWD+IFR+MS 45 4064.89 64.50 7.31 94.90 2856.92 2275.61 2285.32 177.78 2292.22 4.45 0.97 BP_ MWD+IFR+MS 46 4159.45 65.77 7.94 94.56 2896.68 2361.22 2370.35 189.16 2377.89 4.56 1.47 BP_ MWD+IFR+MS 47 4253.42 65.66 7.62 93.97 2935.33 2446.71 2455.22 200.76 2463.41 4.67 0.33 BP_ MWD+IFR+MS 48 4347.98 65.04 7.52 94.56 2974.77 2532.47 2540.41 212.08 2549.25 4.77 0.66 BP_ MWD+IFR+MS 49 4442.49 65.80 7.66 94.51 3014.08 2618.23 2625.60 223.43 2635.09 4.86 0.82 BP_ MWD+IFR+MS 50 4537.09 65.60 7.45 94.60 3053.01 2704.25 2711.07 234.77 2721.22 4.95 0.29 BP _MWD+IFR+MS 51 4632.12 65.86 9.69 95.03 3092.07 2790.78 2796.73 247.68 2807.67 5.06 2.17 BP _MWD+IFR+MS 52 4725.23 67.25 13.72 93.11 3129.13 2876.17 2880.35 265.02 2892.51 5.26 4.24 BP _MWD+IFR+MS 53 4819.56 67.48 18.13 94.33 3165.45 2962.93 2964.04 288.90 2978.09 5.57 4.32 BP _MWD+IFR+MS 54 4914.46 65.47 19.21 94.90 3203.33 3049.23 3046:47 316.75 3062.89 5.94 2.36 BP _MWD+IFR+MS 55 5009.12 65.41 19.61 94.66 3242.67 3134.47 3127.67 345.36 3146.68 6.30 0.39 BP _MWD+IFR+MS 56 5103.04 67.01 19.66 93.92 3280.56 3219.51 3208.61 374.24 3230.36 6.65 1.70 BP _MWD+IFR+MS 57 5197.87 67.32 20.03 94.83 3317.36 3305.95 3290.82 403.91 3315.52 7.00 0.49 BP _MWD+IFR+MS 58 5292.51 67.35 19.71 94.64 3353.83 3392.32 3372.95 433.59 3400.71 7.33 0.31 BP _MWD+IFR+MS 59 5387.76 67.41 19.94 95.25 3390.46 3479.28 3455.66 463.41 3486.60 7.64 0.23 BP _MWD+IFR+MS 60 5486.45 66.67 20.04 98.69 3428.96 3569.12 3541.06 494.48 3575.42 7.95 0.76 BP _MWD+IFR+MS • r~ ~_J [(c)2008 IDEAL ID13_OC_02] SCHLUMBERGER Survey Report 6-Dec-2008 20:50:53 Page 4 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg). (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5582.00 67.32 20.14 95.55 3466.30 3656.05 3623.66 524.69 3661.45 8.24 0.69 BP _MWD+IFR+MS 62 5677.90 68.16 21.10 95.90 3502.63 3743.64 3706.72 555.94 3748.18 8.53 1.27 BP _MWD+IFR+MS 63 5773.44 66.48 20.32 95.54 3539.47 3830.62 3789.17 587.12 3834.39 8.81 1.91 BP _MWD+IFR+MS 64 5868.41 66.21 21.30 94.97 3577.57 3916.42 3870.49 618.02 3919.52 9.07 0.99 BP _MWD+IFR+MS 65 5964.08 65.93 21.81 95.67 3616.38 4002.49 3951.82 650.15 4004.94 9.34 0.57 BP _MWD+IFR+MS 66 6059.47 67.50 22.36 95.39 3654.09 4088.57 4033.01 683.10 4090.45 9.61 1.73 BP _MWD+IFR+MS 67 6155.01 66.96 22.13 95.54 3691.06 4175.07 4114.54 716.44 4176.45 9.88 0.61 BP _MWD+IFR+MS 68 6250.42 66.48 23.43 95.41 3728.77 4260.98 4195.35 750.38 4261.93 10.14 1.35 BP _MWD+IFR+MS • 69 6346.30 67.95 24.23 95.88 3765.90 4347.28 4276.21 786.09 4347.86 10.42 1.72 BP _MWD+IFR+MS 70 6442.18 68.39 23.42 95.88 3801.56 4434.18 4357.63 822.04 4434.48 10.68 0.91 BP _MWD+IFR+MS 71 6537.83 67.41 24.11 95.65 3837.54 4520.73 4438.73 857.76 4520.85 10.94 1.22 BP _MWD+IFR+MS 72 6633.61 67.18 24.24 95.78 3874.51 4606.89 4519.34 893.94 4606.90 11.19 0.27 BP _MWD+IFR+MS 73 6715.37 69.09 22.70 81.76 3904.96 4681.07 4588.94 924.15 4681.07 11.39 2.92 BP _MWD+IFR+MS 74 6824.45 67.73 21.66 109.08 3945.10 4780.68 4682.85 962.44 4780.74 11.61 1.53 BP _MWD+IFR+MS 75 6920.26 67.24 22.14 95.81 3981.79 4867.69 4764.97 995.46 4867.85 11.80 0.69 BP _MWD+IFR+MS 76 7015.91 68.77 22.12 95.65 4017.61 4954.82 4847.13 1028.86 4955.12 11.98 1.60 BP _MWD+IFR+MS 77 7111.41 68.00 21.92 95.50 4052.79 5042.06 4929.43 1062.15 5042.57 12.16 0.83 BP _MWD+IFR+MS 78 7207.58 67.36 21.65 96.17 4089.31 5129.56 5012.04 1095.17 5130.30 12.33 0.71 BP _MWD+IFR+MS 79 7303.14 68.04 21.82 95.56 4125.57 5216.52 5094.17 1127.91 5217.54 12.48 0.73 BP _MWD+IFR+MS 80 7397.55 67.73 21.57 94.41 4161.12 5302.56 5175.44 1160.24 5303.90 12.64 0.41 BP _MWD+IFR+MS 81 7492.89 66.70 20.65 95.34 4198.04 5389.19 5257.44 1191.90 5390.85 12.77 1.40 BP _MWD+IFR+MS 82 7589.03 67.47 21.13 96.14 4235.47 5476.52 5340.17 1223.48 5478.53 12.90 0.92 BP _MWD+IFR+MS 83 7684.70 68.59 21.18 95.67 4271.26 5563.94 5422.91 1255.50 5566.35 13.04 1.17 BP • _MWD+IFR+MS 84 7780.09 68.56 21.49 95.39 4306.11 5651.39 5505.62 1287.80 5654.23 13.17 0.30 BP _MWD+IFR+MS 85 7876.37 67.66 21.32 96.28 4342.00 5739.36 5588.80 1320.41 5742.66 13.29 0.95 BP _MWD+IFR+MS 86 7968.80 69.55 21.14 92.43 4375.72 5824.14 5669.01 1351.57 5827.90 13.41 2.05 BP _MWD+IFR+MS 87 8067.31 67.33 18.32 98.51 4411.92 5914.76 5755.23 1382.51 5918.95 13.51 3.49 BP _MWD+IFR+MS 88 8162.55 66.17 14.76 95.24 4449.53 6001.88 5839.09 1407.43 6006.32 13.55 3.64 BP _MWD+IFR+MS 89 8258.28 65.37 9.87 95.73 4488.84 6089.13 5924.34 1426.05 6093.56 13.53 4.73 BP _MWD+IFR+MS 90 8353.89 64.82 8.29 95.61 4529.10 6175.78 6009.97 1439.74 6180.02 13.47 1.61 BP _MWD+IFR+MS ~ [(c)2008 IDEAL ID13_OC_02] SCHLUMBERGER Survey Report 6 -Dec-2008 20:50:53 Page 5 of 5 , Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (f t) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 -------- 8449.93 ------ 63.65 ------- 5.71 96.04 4570.85 6262.01 6095.81 1450.29 6265.95 13.38 2.71 BP _MWD+IFR+MS 92 8545.25 63.17 1.47 95.32 4613.53 6346.44 6180.85 1455.63 6349.94 13.25 4.01 BP _MWD+IFR+MS 93 8639.26 62.81 1.21 94.01 4656.23 6428.92 6264.58 1457.59 6431.92 13.10 0.46 BP _MWD+IFR+MS 94 8735.84 63.24 0.96 96.58 4700.04 6513.62 6350.64 1459.22 6516.13 12.94 0.50 BP _MWD+IFR+MS 95 8831.42 62.94 0.83 95.58 4743.30 6597.43 6435.86 1460.55 6599.51 12.79 0.34 BP _MWD+IFR+MS 96 8926.71 63.37 0.66 95.29 4786.33 6681.00 6520.87 1461.65 6682.68 12.63 0.48 BP _MWD+IFR+MS 97 9021.35 60.92 1.25 94.64 4830.54 6763.30 6604.53 1463.04 6764.64 12.49 2.65 BP _MWD+IFR+MS 98 9117.98 60.81 0.51 96.63 4877.59 6846.29 6688.92 1464.34 6847.33 12.35 0.68 BP _MWD+IFR+MS 99 9213.25 60.56 0.79 95.27 4924.23 6927.92 6771.99 1465.28 6928.70 12.21 0.37 BP • _MWD+IFR+MS 100 9308.38 60.52 0.29 95.13 4971.02 7009.28 6854.81 1466.06 7009.84 12.07 0.46 BP _MWD+IFR+MS 101 9404.24 60.87 0.30 95.86 5017.94 7091.32 6938.40 1466.49 7091.69 11.93 0.37 BP _MWD+IFR+MS 102 9499.72 61.52 0.62 95.48 5063.95 7173.48 7022.07 1467.17 7173.70 11.80 0.74 BP _MWD+IFR+MS 103 9594.95 58.85 2.89 95.23 5111.29 7254.93 7104.64 1469.67 7255.05 11.69 3.48 BP _MWD+IFR+MS 104 9690.75 57.66 2.75 95.80 5161.70 7335.49 7186.01 1473.68 7335.56 11.59 1.25 BP _MWD+IFR+MS 105 9786.81 58.29 2.90 96.06 5212.64 7416.03 7267.35 1477.70 7416.06 11.49 0.67 BP _MWD+IFR+MS 106 9882.61 58.33 2.70 95.80 5262.96 7496.65 7348.77 1481.68 7496.65 11.40 0.18 BP _MWD+IFR+MS 107 9977.83 58.44 2.81 95.22 5312.88 7576.82 7429.76 1485.58 7576.83 11.31 0.15 BP _MWD+IFR+MS 108 10020.77 58.16 2.66 42.94 5335.44 7612.94 7466.25 1487.32 7612.95 11.27 0.72 BP _MWD+IFR+MS 109 10080.00 58.16 2.66 59.23 5366.69 7662.68 7516.52 1489.65 7662.71 11.21 0.00 Pr oject to TD [(c)2008 IDEAL ID13_OC_02] i jSehlumherger Drilling & Measurements MWD/LWD Log Product Delivery Customer Well No Installation/Rig BP Exploration (Alaska) Inc W-218 9ES Dispatched To: Date Dispatched Dispatched By: Christine Mahnken 12-Dec-08 Paul Wyman Data No Of Prints No of Floppies Surveys 2 1 Received By: Please sign and return to: Drilling & Measurements LWD Division 1 ~ ~~~ ~~ ~ "'~ 2525 Gambell Street, Suite 400 Anchorage, Alaska 99501 puvymanC~slb.com Fax:907-561-8317 LWD Log Delivery V2.1, 03-06-06 Page 1 of 1 Maunder, Thomas E (DOA) From: Crisp, John H (DOA) Sent: Tuesday, December 02, 2008 5:56 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Noble, Robert C (DOA) Subject: Cement to Surface on PBU W Pad 2181 Call this morning @ 0315 hrs. from Nabors 9ES about the need to perform a Top Job on their Surface Casing My response was that they could not proceed with any Top Cement job until approved by AOGCC Anchorage Office. t told the Drilling Foreman that there seemed to be quite a few surface casing strings lately that did not meet State regulations by having cement to surface. This would probably be an issue that would be discussed with AOGCC Anchorage. The Drilling Foreman was made aware that North Slope Inspectors could not & would not ever give permission for Top Jobs. The Foreman stated that he most probably would prepare for the job in anticipation of approval from AOGCC Anchorage Office. 2/9/2009 W-218i Surface Casing Top J~ ~ Page 1 of 2 Maunder, Thomas E-(DOA) From: Staudinger, Garret [Garret.Staudinger@bp.com] Sent: Tuesday, December 02, 2008 9:22 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: RE: W-2181 Surface Casing Top Job Tom, 1. The pipe was reciprocated in 10' strokes. The hanger was landed on the ring 440 bbls into pumping lead cement due to low slack off weight. 2, The total displacement was 384 bbls of 9.5 ppg Spud Mud 3. The 131 bbls is equivalent to 1845 strokes. The 131 bbls is what the IADC sheet was closed out at midnight. 4. The returns did slowly started decreasing prior to packing off. Sorry for the confusion. Hope this helps. -Garret Staudinger __ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, December 02, 2008 9:08 AM To: Staudinger, Garret Cc: Regg, James B (DOA) Subject: RE: W-218i Surface Casing Top Job Gan°et, Thanks for the summary. Same questions ... 1. Was the pipe reciprocated? 2. What was the total displacement? I calculated 395 bbls. 3. Are the 131 bbl volume and 1100 strokes "equivalent"? 4. Did returns decrease while pumping prior to pack-off? Tom Maunder, PE AOGCC From: Staudinger, Garret [mailto:Garret.Staudinger@bp.com] Sent: Tuesday, December 02, 2008 8:53 AM To: Maunder, Thomas E (DOA) Subject: W-218i Surface Casing Top Job Tom, The following is a summary of events during the surface cement job on W-2181 last night: - Pumped 71 bbls of 10.0 ppg MudPush II @ 5 bpm. - Shut down and unsting TESCO tool from landing joint. Drop bottom plug and sting TESCO tool back into landing joint. - Pump 621 bbls of 10.7 ppg DeepCrete lead cement - Pump 86 bbls of 15.8 ppg Class "G" tail cement - Unsting from landing joint and drop top plug. Sting back into landing joint and chase with 10 bbls H2O. Full returns throughout cement pumping 2/5/2009 W-218i Surface Casing Top J~ • Page 2 of 2 - Switch over to rig pumps and begin displacing cement with 131 bbls 9.5 ppg Spud Mud. - At 1100 strokes into displacement, increase rate to 4 bpm, 1465 psi ICP, 1440 psi FCP. - At 2100 strokes -decrease rate back to 3 bpm, 1215 psi ICP, 1590 psi FCP. - At 4100 strokes -decrease to 2 bpm, 1590 psi ICP, 1965 psi FCP. - At 4700 strokes -hole packed off with no returns to surface. - At 4950 strokes -divert flow to cellar to ensure landing ring was not packed off. No flow in cellar. - Bumped plug @ 5538 strokes at 2900 psi and pressure up to 3350 psi. - Bleed off pressure, floats held - PT casing to 3500 psi -good 9-5/8" casing shoe @ 5461' CIP @ 01:48 hrs. No cement or MudPush back to surface. At this time a top job is planned to bring cement to surface. Please let me know if you need any additional information. Thanks, Garret Garret Staudinger Operations Drilling Engineer BP Exploration Alaska, Inc. Work: (907) 564-4242 Cell: (907) 440-6892 2/5/2009 • Maunder, Thomas E (DOA) From: Hobbs, Greg S (ANC) [Greg.Hobbs@bp.com] Sent: Tuesday, December 02, 2008 12:33 PM To: Maunder, Thomas E (DOA) Cc: Schultz, Mikel; Tirpack, Robert B Subject: RE: Surface Casing Cementing Tom- • Page 1 of 2 The W-218 well was the second well that we ran the Tesco Casing running system on which allows the pipe to be rotated if needed to get it to bottom. This system and its potential impact on the TAM collar on the H-38 well is still being looked into. Given the tap job volumes pumped, it is my opinion that cement was not around the collar, which leads us to believe that while the shifting tool engaged the collar, it did not shift it open as was thought when it held the 1500 psi pressure after "opening". We are also looking into the cement on H-38 as it seemed to dehydrate leading to an internal pack-off as was indicated by not being able to pump the jab away after it locked up. We held the ticket and will have discussions with Schlumberger. Regarding W-218, the main reason the TAM was not run was there were no issues with losses during the drilling or the casing running operations on the well. We have chosen not to run the TAM in these cases as we have inadvertantly functioned TAM collars with Ghost Reamers in the past. The W-218 pack-off was unforseen, there was no significant amounts of gravel or wood in returns while drilling, an bottoms up, or running casing. We are looking at an MI "Dril-Plex"' system to aid in holding back gravels found in the main field surface holes. We are uncertain of the applicability of this system in the WRD due to hydrate potential there. We are looking into that issue. Below is the opinion of the BP mud expert on our use of the Mixed Metal Oxide (Dril-Flex) system. John, We have used Ml's MMO in big hales to clean gravel, big cuttings, reduce down hole mud losses, MMO is a very efficient system to do this kind of job. MMO has excellent rheological and thixotropical properties, so for your application is very good. MMO has very poor properties for shale stability and the filtrate is high, but in your case I think it will be good. We used MMO in Argentina in a very similar situation; I can get additional information on the Argentina's case. Regards, JC, Fluids Specialist - EPT OfFce: 281 366 4605 Mobile 713 539 5899 e-mail roj~ca@bp.com Our current actions are to close the issues as best we can with the H-38 cement and the impact of rotating the TAM collar with the TESCO system. We are doing a trial run of the Dril-Flex system on the R-41 spud on 7es 2/5/2009 ~~ Page 2 of 2 later this month. I will follow up with you on what we find. Duncan Ferguson, the well site leader on 7es during the H-38 surface run felt that the TESCO system was indispensible. We like the tool and want to continue to run it without impacting our ability to bring cement to surface. Please let us know if you have any other questions- Greg (with input from Rob) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, December 02, 2008 8:26 AM To: Tirpack, Robert B; Hobbs, Greg S (ANC) Cc: Regg, James B (DOA) Subject: Surface Casing Cementing I was notified this morning that cement was not circulated to surface on W-218. I just spoke with Garrett and he indicated that the operation was apparently proceeding smoothly until the hole started to pack-off. This is the 2"d surface job of late when difficulties were encountered. I suspect that there is a lot of work underway on remedying and dealing with these problems. We would appreciate a message discussing the options that are being considered. I know a port collar was run in the recent case (messaged/discussed with Greg however it was not able to be manipulated. In this case, no port collar was run based on what was experienced drilling the hole. I look forward to your reply. Tom Maunder, PE AOGCC 2/5/2009 • Maunder, Thomas E (DOA) S Page 1 of 1 From: Staudinger, Garret [Garret.Staudinger@bp.com] Sent: Thursday, November 13, 2008 8:59 AM To: Maunder, Thomas E (DOA) Subject: RE: W-218 Attachments: Tesco CDS Summary -rev 1.doc; Tesco Product info.zip Tom, Attached is some information I have on the Tesco CDS tool. Let me know if you have any additional questions. Thanks, Garret From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, November 10, 2008 1:53 PM To: Staudinger, Garret; Peltier, Brandon Subject: W-218 Garret or Brandon, I am reviewing the permit application for this well. I believe Brandon had called regarding the contingency 13-3/8" "conductor". I see that contingency is mentioned, however it is stated that the contingency string will only be ~~ optioned if running the 9-5/8 casing with the Tesco CDS (casing drilling system) fails. I'd appreciate some further information on how the contingency comes into play as well as information on the CDS system. Thank in advance. Tom Maunder, PE AOGCC 2/5/2009 • Maunder, Thomas E (DOA) Page 1 of 1 From: Staudinger, Garret [Garret.Staudinger@bp.com] Sent: Wednesday, November 1 Z, 2008 10:28 AM To: Maunder, Thomas E (DOA); Peltier, Brandon Subject: RE: W-218 AGAIN Tom, W-204 is the only well within 1/4 mile of W-218. There are no other wells targeting any other horizon that are within 1/4 mile of W-218 through the Schrader. I also wanted to let you know that W-218 has moved up in the drilling schedule to spud after V-219. This means that the es#imaF6e4f 'fclr V1h218 i8lwovenzPier 2~4, 2008: This scheduling change is due to funding. Let me know if you have any questions. Thanks, Garret From: Maunder, Thomas E (DOA) [maifto:tom.maunder@alaska.gov] Sent: Monday, November 10, 2008 2:03 PM To: Maunder, Thomas E (DOA); Staudinger, Garret; Peltier, Brandon Subject: RE: W-218 AGAIN Garret or Brandon, You identify that W-204 is within '/< mile of W-218 in the Schrader. Are there any other wells targeting Sadlerochit or Kuparuk horizons that exist within % mile of the W-218 trajectory through the Schrader? Thanks again, Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, November 10, 2008 1:53 PM To: Staudinger, Garret; 'Peltier, Brandon' Subject: W-218 Garret or Brandon, I am reviewing the permit application for this well. I believe Brandon had called regarding the contingency 13-3/8" "conductor". I see that contingency is mentioned, however it is stated that the contingency string will only be optioned if running the 9-5/8" casing with the Tesco CDS (casing drilling system) fails. I'd appreciate some further information on how the contingency comes into play as well as information on the CDS system. Thank in advance. Tom Maunder, PE AOGCC 11112/2008 W-218i PTD Surface Casing Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, November 07, 2008 9:28 AM To: 'Peltier, Brandon' Cc: Tirpack, Robert B; Staudinger, Garret Subject: RE: W-2181 PTD Surface Casing Brandon, This is not an issue. I will place a copy of this message in the well file. Tom Maunder, PE AOGCC Page 1 of 2 From: Peltier, Brandon [mailto:Brandon.Peltier@bp.com] Sent: Friday, November 07, 2008 9:04 AM To: Maunder, Thomas E (DOA) Cc: Tirpack, Robert B; Staudinger, Garret Subject: RE: W-218i PTD Surface Casing Your correct, I mistyped the new weight of the casing. It will be 47#. I apologize about the confusion. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) s64-s912 (D;rect> (907) 748-7838 (Mobile) Brandon.Peltier@bp.com From: Maunder, Thomas E (DOA) [maiito:tom.maunder@alaska.gov] Sent: Friday, November 07, 2008 8:18 AM To: Peltier, Brandon Cc: Tirpack, Robert B; Staudinger, Garret Subject: RE: W-2181 PTD Surface Casing Brandon, I thought there was a weight change from 40 to 47#. Did I misunderstand? Thanks, Tom Maunder, PE AOGCC From: Peltier, Brandon [mailto:Brandon.Peltier@bp.com] Sent: Friday, November 07, 200$ 6:47 AM To: Maunder, Thomas E (DOA) Cc: Tirpack, Robert B; Staudinger, Garret Subject: W-218i PTD Surface Casing Tom As we discussed on the phone yesterday, we will have to change the weight of our surface casing on W 2181. The recently submitted W-2181 permit specifies 9-5/8", L-80, 40#, BTC casing, but that will be changed to 9-518", 11/7/2008 W-2181 PTD Surface Casing ~ ~ Page 2 of 2 L-80, 40#, BTCM casing due to availabilty. We will also drill an 8.5" production hole section instead of the 8.75" in the PTD, but the fundamental well design will not change. Please let me know if you have any questions. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct) (907) 748-7838 (Mobile) Brandon. Peltier@bp. com 11 /7/2008 • Tesco Casing Drive System Tool (CDST"~ Assessment Intended Application for W-217i & W-218i Spud dates: Nov 25"', 2008 & Dec 15th, 2008 Date of Assessment: September 5, 2008 Author: Bob Coolidge, ODE WRD BPXA Back rg; ound: W-pad has exhibited abnormally high risks of getting 9 5/8" casing to TD due to gravel running in the PF. If 9 5/8" casing does not eventually get set into the top of the SV 1, the LOT will not be sufficient to continue drilling as planned, and the well's objectives are at risk. BP Requirements/Strateey: WRD Drilling has been investigating the use of this new equipment, with a vision that all 3 WRD rigs might eventually use this type of casing running tool. W-217i and W-2181 are AFE'ed with a primary well design including drilling 16" hole/13 3/8" "gravel string", with associated costs of +/-$750K each. The WRD team believes we can mitigate the need of this 13 3/8" string if by adding the ability rotate / "drill in" our 9 5/8" casing. Current casing running practices and equipment allow only reciprocation and circulation. Recommendation: Use the Tesco CDS tool for these two wells, with post job assessment and any minor modifications being made prior to the 2"d well. To facilitate cementing, place apump-in sub (PS) with a TIW below it, between the top drive and the CDS. The PS is preferred to have a swivel on each end, but this is not a requirement. (3rd party equipment not supplied by Tesco). Thinning of the mud prior to cementing can be started so that it is completed when casing reaches TD, so that cementing can be begun immediately. Proposed Casing Plan: The plan is generally the same as any other USH well plan on pads OTHER THAN W-pad. • Plan cement job as single stage with normal cement excess volumes. • Run TAM port collar, but likely place it near 500-600' MD as contingency (review data from geology). • Be prepared to request state permission to perform Top Job remediation (if cmt still does not reach surface). Safe • CDS eliminates the role of the "stabber", the use of power tongs (moving parts/pinch points/high tension cables) & elevated platforms. • People on the rig floor (falls, line of fire for dropped objects/equipment impact) reduced to only one operator of the CDS hydraulic unit, which is placed in a safe position. • Safety statistics support that a casing running tool of this sort improves safety. • Attached IADC magazine article provides additional detail. Commercial: • Expected two-well savings (tangibles/intangibles) is $1.2-1.7M. • Use of the system is not required, but is expected, for the 2nd Process changes will be made to improve operations on the 2"d well. • This savings is too large for us to NOT assure that tools available. • Time savings • • o Even if rotation is not needed to get casing to TD, time savings is expected, and it will be quantified during these well operations. o Thin the mud by the time csg is run to bottom, but don't start too soon. o If running gravels occur, the enhanced capability to rotate the string (utilize a drilling shoe) is expected to be the difference that will allow the 9 5/8" casing to reach TD as planned. Frank's Fill-Up tool - Not needed ($4000/job savings) Nabors' Contract is interpreted to mean we will NOT pay for casing running services ($1.75/ft for surface csg = $8000/job for Nabors' csg tongs and an extra crew member) Reference Tesco commercial proposal & ODE cost summary estimate. Technical: • RU/RD- o Frank's mud fill-up tool is not needed. o Tesco tool is twelve (12) feet long, is a single "lift", and derrick height is sufficient. Running Casing and Rotating- o The Tesco CDS is run under the top drive. The CDS utilizes a hydraulic power unit placed in a convenient spot on the rig floor, and is run by one operator whose actions are coordinated with the driller who is operating the top drive. o A WarthogTM reamer shoe is pre-installed in the shop. It contains a float shoe. o The reamer shoe will be subsequently drilled out. o Torque rings are added to connections off-line in the pipe shed prior to running casing. o Centralizers can either be attached in the pipe shed with a crimping tool to hold them in fixed position, allowed to float free on the joints. Sitting static on bottom after casing reaches TD is virtually eliminated by cementing with the CDS and PS. o IF the PS does NOT have swivels, then a line must be MU & Tested (15 minutes). o IF the PS has a swivel above and below it, then the cementing line can be pressure tested when RU, and remain hooked up during the running of casing, if we so choose. This will require a SOOOpsi flexible hose, instead of hard pipe. MOC required for RU, cementing & RD with the Tesco CDS tool / PS. A rig assessment for 9ES was completed this summer by Tesco. We are awaiting their report, but the results were reported to be acceptable to Tesco. o Launch 1St plug manually (manually place "bottom plug" into top of open top casing stub, attach CDS, pump cement). Opening up pipe to drop the ball is similar to opening pipe to drop a liner job dart. o Top plug is pre-loaded/attached to the bottom of the CDS tool. Procedure would involve EITHER: ^ backing-off the top drive from upper PS connection, drop ball, re- connect top drive (man in man-rider up 15-20 feet above rig floor is required to load ball), ball seats in "top" plug, and will pressure up to shear and send top plug. ^ The ball drop should be performed by the ball launcher that is in the PS/TIW tools (ball size to be agreed upon based on plug design) o Plugs ARE NOT NON-ROTATING PLUGS which means: ^ increased time to drill out (3-4 hours) ^ Recommend pumping 1-3 bbls of cement behind the top plug Developed for the rigors of CASING DRILLING' , the TE (CDS")delivers all of the advantages of Top Drive drilling t tion. Replacing power tongs and traveling elevators the CD tion, reciprocation and circulation of the casing string at any and the chance of getting casing into troublesome wellbore CDS" as part of afull-service Casing Running offering. Easily er's Tap Drive system and with a track record of millions of Industry's most versatile and proven integrated drive taol. The TESCO CDS" can be quickly installed on virtually any l ` hydraulic, with typically no modifications to any existing dril The TESCO CDS' greatly reduces the amount of equipmei run casing, provides a high level of mechanization keeping pe ~' and places the Casing Running operation under the control -,: ~._ sing Drive System" sing Running opera- } simultaneous rota- alyincreasing safety ~ now provides the on any manufactur- fES000DS" is the ~ ,,„ system, electric or ment. rsonnel required to gut of the line of fire •iller. ~I FEATURES AND OPERATION g,:~; An integrated link tilt system incorporating extendable bails and hydraulic single joint ~ elevators with a safety interlock enables the casing to be picked up at the V-door, ;~ eliminating manual single joint elevators and greatly reducing effort, fatigue and injury risk from personnel-machinery proximity • The single joint is hoisted, positioned over hole center and stabbed through lowering ~ f~ ~ fix the Top Drive ~ ~~ t°.r~ • The CDS' grapples engage the casing, and the joint is spun-up using the Top Drive ~~ , ~~ motor A smooth make-up with no bending load and precise control on final torque is easily t~~; attained by use of the Tap Drive system ,KKK-~. . n„~p rr,P rnnnPrtinn s~ assembled circulation can be initiated and the CDS'" used to ~~ • The CDSTM replan used to lower the • When used with a For premium co nections, the Te: be provided. Te versus turns and. and reporting pa TesTORKTM can or hydraulic Tap i e the entire string of casing, greatly reducing the chance of :ling elevators, and supporting the entire casing string load, is ~. string into the well ider assembly the CDS"" allows the stump to be set at a com- ~liminating the need for raised working platforms -R1NG AND RECORDING - ~, or as added security to qualify con- ~ nonitoring and reporting system can = captures, graphs and reports torque ;~ nd with a comprehensive acquisition valuable element in the audit trail .~ 'th virtually any electric (AC or DC} -~ :em. is • ~~ ' The TESCO CDS" adds real value through reducing the risks associated with Casing Running, and by improving the efficiency of the operation. For all of the same reasons why a Top Drive improves efficiency and enhances safety, the CDS" virtually eliminates the chance of unscheduled events, such as: • Setting casing short of the casing point due to hole obstructions • Stuck pipe as can occur when the casing string remains stationary • Well control situations that can occur due to hole surging or inadequate casing fill • Use of circulating swedges and the attendant risk of connection damage • Working pipe through tight spots, across ledges or bridges by using the power tongs to rotate the casing • Pulling casing following a refusal and subsequent hole conditioning, driApipe work and associated re-running of the casing By using the capabilities of the Top Drive system in the rig, the CDS' also eliminates risks associated with equipment and other operations, such as: • Power tongs, suspension lines or back-up lines in the derrick or on the rig floor • Large traveling elevators • Elevated work platform or scaffolding at the rig floor • Separate fill-up/circulating tool or line • Personnel working at heights or out of the Driller's line of sight Most importantly, by eliminating the need for workers at heights or out of the Driller's line of sight, the safety of any Casing Running operation can be greatly ~' enhanced. .:~ CASING REAMING OPERATIONS Casing Reaming can be a viable option in areas where hole problems are com- monplace and where simply circulating and rotating the casing will not be ad- equate to convey the string to the casing point. In these applications, as the world-leader in CASING DRILLING`, TESCO's proprietary technology can be employed to greatly increase the chances of getting the casing to the desired depth. To help ensure a successful job, TESCO can provide: • Operational modeling using TESCO's CD-Frig" CASING DRILLING" software to analyze torque, drag, hydraulics, fatigue and buckling loads. • Proprietary Casing Accessories desgneo to enaoie conventional casing to be reamed into the well without compromising the integrity of the casing string or connections. These include MLT" rings to increase the torque capacity of API connections; hard-faced wear bands to prevent casing and meriting; the Guide Shoes • For extreme ployed. Aftf Profile Nippl of CASING I and ability of uon, virtuall} ~~~. in abrasive formations; Hydro-Form'" centralizers and sta- ure proper mechanical centralization of the casing for ce- ~w Warthog" Casing Reaming Shoe; and, a variety of Casing pith or without cutting structure. difficult holes, the full CASING DRILLING" BHA can be em- conventionally drilling the interval a CASING DRILLING'" can be installed as part of the casing string, and a full suite BILLING'tools can then be landed in the string. The power full drilling assembly can be brought to the reaming opera- ;uaranteeing that the string will reach full total depth. ~., ~- Casing Guide Shoes Corporate Headquarters 6104 - 6~ Street S.E. Calgary; =+iGes~a, Canada 32H 2B7 T~:i: 463 233-0'57 • Fax: 4~~3 252-3362 V'Jorld ~~Idn {~peratdons 1-1330 Eritims~are Park ~sive Nn.;stan, I>axa;, lsS~? 770=r1 Tai: 713 6=~9-`;3Q6 • Fax' ;':3 8~~-40"5 ~' ~ ~~ ALASSA OIL A1~TD GA5 CO1~5ERQATIOI~T COMnII55IO1~ Robert Tirpack Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Polaris Oil Pool, PBU W-218 BP Exploration Alaska Inc. Permit No: 208-174 Surface Location: 4964' FSL, 1175' FEL, SEC. 21, T11N, R12E, UM Bottomhole Location: 1900' FSL, 346' FWL, SEC. 10, T11N, R12E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced service 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, Daniel T. Seamount, Jr. Chair ~3 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. DATED thi -day of November, 2008 ~~~ 02 d STATE OF ALASKA ALAS'!401L AND GAS CONSERVATION PERMIT TO DRILL 20 AAC 25.005 ".~~ 1 a. Type of work ® Drill ^Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU W-218 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10168' TVD 5391' 12. Field /Pool(s): Prudhoe Bay Field /Polaris Pool 4a. Location of Well (Governmental Section): Surface: ' E ' 7. Property Designation: ADL 028263 & 028261 4964 FSL, 1175 FEL, SEC. 21, T11N, R12 , UM Top of Productive Horizon: 2558' FSL, 895' FEL, SEC. 16, T11 N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 27, 2008 Total Depth: 1900' FSL, 346' FWL, SEC. 10, T11 N, R12E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 23,920' 4b. Location of Well (State Base Plane Coordinates): Surface: x-612049 y-5959941 Zone- 10. KB Elevation Plan (Height above GL): ,7 feet 15. Distance to Nearest Well Within Pool: 1,300' 16. Deviated Wells: Kickoff Depth: 250 feet Maximum Hole An le: 69 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2438 Surface: 1899 1 in Pr r m: ifi n To - S i h- B m n' f .f. r a Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4" 1. WI rf Ar A r . 1 -1 /4" -/" 4 T rf rf 7 x t 411 x s" / " " TCII / BTC-M 1 ' ' ' 1 g. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (tt): Total Depth TVD (it): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (tt): Junk (measured): asing Length ize ement Volume- MD TVD Conductor /Structural Surface Intermediate Liner Perforation Depth MD (tt): Perforation Depth TVD (tt): 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ 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 Garret Staudinger, 564-a2a2 Printed Name Ro 'pack Title Engineering Team Leader Prepared By NameMumber: Si nature Phone 564-4166 Date ~~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill N m r: v?O - API Number: 50- Oa9®?3•bl0,30000 Permit Approv~ I p See cover letter for Conditions of Approval: ~ ~ ~' i ~.'~cc C)~c,'t~,~LCh`\r CsLCSJ ~ ~ Q ~'Q ~O A 'Cs i~Cy P QC(joc-C~ e If box is checked, well may of be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: iT ~.~' ~~v`~ VG`C°~`C1 S Sam les R d: ~, p eq' ^ilfes ~No Mud Log Req'd: ^ Yes ~No ~id~ ~ ~ ~~~ ,~,~\ HZS Measures: ~ Yes ^ cN~o Directional Survey Req'd: Yes ^ No Other: ~0~ ~ ~CL. c'~C~pvcj.`~~0-CCC~' ~.~ ~(c ~ rQ~, ~ ~A~~~ :O ~ ~ \~ ~" ~ .-~ ~ APPROVED BY THE COMMISSION Date ,~ - : COMMISSIONER Form 10-401" Revised 12/2005 5ubmlt In Uupucate 1 t_~~ L.. Well Name: W-218i Drill and Complete Plan Summary Name Position Office Home Cell Garret Staudin er Drillin En ineer 4242 440-6892 440-6892 Gre Bernaski Geolo ist 5464 346-1320 440-8002 E or Makarov Pad En ineer 5687 743-6915 229-0215 T e of Well service / roducer / in'ector : Injector Surface Northin Eastin Offsets TRS Location 5,959,941 612,049 4963' FSL / 1175' FEL 11 N, 12E, 21 Northin Eastin TVDss Offsets TRS Target 5,962,819 612,279 -3,065 2558' FSL / 895' FEL 11 N, 12E, 16 Locations 5,966,900 613,430 -4950 1342' FSL / 4954' FEL 11 N, 12E, 10 5,967,150 613,435 -5,105 1592' FSL / 4945' FEL 11 N, 12E, 10 Bottom Northin Eastin TVDss Offsets TRS Location 5,967,458 613,441 -5,309 1900' FSL / 4934' FEL 11 N, 12E, 10 API NUMBER: TBD Ri Nabors 9ES Estimated Start Date: 12/27/2008 O eratin Da s to com lete: 23.5 MD: 10168' TVD: 5391' RT/GL: 28.5'/53.2' RTE: 81.7' Well Design: Grassroots Schrader Bluff Injector 3'h" tbg, 9.2# L80, TC-II, multi-packers, zonal injection Ob'ective: Multi-zonal in~ector into Schrader Bluff OBa, OBc and OBd sands Directional Plan: Version: Schlumber er P7 KOP: 250' MD, build 1.5/100 Maximum Hole An le: 68° Close Approach Wells: Nearest well within Pool All wells pass major risk criteria. Reference anti-collision report W-218 is 1300' from W-204 in SB_OBd slotted liner interval Distance to Nearest Property Line: 23,920' to PBU boundary W-2181 Permit Application Page 1 Wells within 1/a mile of this infection well: Well Name Dist, Ft. Annulus Inte rit Comments W-204 1300' C~ SB_OBd W-204 multi-lateral well SB_OBd sand slotted liner completion. W-204 is a production well which will be supported by the W- 218i in'ector. Logging Program: Surface Interval Drilling, MWD: GR Open Hole: None Cased Hole: None Intermediate Interval Drilling, MWD: N/A Open Hole: N/A Cased Hole: N/A Production Interval Drilling, MWD: GR, RES, NEU, Azimuthal Density PWD Open Hole: None Cased Hole: USIT Prima De th Control mode Mud Program: 16" (if neededl & 12 ~/a" Surface Hole: Fresh Water Surface Hole Mud Densi Viscositv seconds Yield Point Ib/1~ API FL mis/30min ~H Initial 8.8 - 9.2 +400, 300 final 50 - 70 NC - 8.0 8.5 - 9.5 Base PF to to SV 9.0 - 9.5 250-300 60 - 55 < 8.0 9.0 - 9.5 SV to TD 9.5 max 250-300 60 - 45 < 8.0 9.0 - 9.5 8 3/a" Production Hole: LSND Interval Density (pp) YP PV pH API Fluid Loss Cs Shoe to TD 8.8-9.0 18-24 12-18 9-10 <6.0 Casinq/Tubinq Program: Hole Size Csg/ Tb O.D. WUFt Grade Connection Length Top MD/TVD Btm MD/TVD RTE 42" Insulated 20" 91.5 A-53 WLD 80' GL 80'/ 80' 16" (Conting ency Plan 13 /8" 68 L-80 BTC 1393' GL 1393' / 1382' 12'/a" 9 /8" 40 L-80 BTC 5483' GL 5483' / 3396' 8 3/a" 7" 26 L-80 TC-II 6983' GL 6983' / 3610' 8 3/a" 7" 26 L-80 BTC-M 3185' 6983' / 3610' 10168' / 5390' Tubin 3'/z" 9.2 L-80 TC-II 10048' GL 9905' / 4781' ~ Comments: ~ Tbg crossover to 4'/z" just below tree W-218i Permit Application Page 2 i I me rit Testi n Test Point Depth Test Type 9 5/g" Surface Casing 20' - 50' from surface shoe LOT Contingency Plan: The 12 ~/a" hole will be drilled with a diverter, therefore no FIT or LOT will be performed after drilling out the 13 3/8". In accordance with AOGCC 20 AAC 25.030.f. Cement Calculations: Second Conductor Contingency Plan): Casing Size 13 /$" Basis: Lead: Based on 400' open hole volume + 350% excess in permafrost and 80' shoe track volume. TOC from 110' to surface throw h TAM Port Collar. Total Cement Volume: Lead 167 bbls / 936 ft / 742 sks of DeepCrete 10.7 ppg and 4.44 cf/sk. Surface Casin Casing Size 9 /$" Basis: Lead: Open hole volume +250% excess in permafrost and 40% excess below permafrost. Port collar used if necessary. Lead TOC: Surface Tail: Open hole volume + 40% excess + 80' shoe track. Tail TOC: 1000' MD above the Casin shoe 4483' MD Total Cement Volume: Lead 598 bbl / 3358 ft / 756 sks of DeepCrete at 10.7 ppg and 4.44 cf/sk Tail 84 bbl / 472 ft / 411 sks of Class `G' at 15.8 ooa and 1.16 cf/sk Production Casin Casina Size 7" Basis: Lead: Open hole volume with 40% excess Lead TOC: 6483' (1000' MD below surface casing shoe Tail: Open hole volume with 40% excess and 80' shoe track volume, ID 6.276" Tail TOC: 8075' (500' MD above Ma) Total Cement Volume: Lead 60 bbl / 335 ft / 142 sks of LiteCRETE at 12.0 ppg and 2.36 cf/sk Tail 82 bbl / 458 ft / 395 sks of Class `G' at 15.8 ppa and 1.16 cf/sk W-218i Permit Application Page 3 ~1 ~._ ~ Formation To s TVDss and Estimated Pore Pressures Est. Formation To s Uncertain Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Formation TVDss feet Yes/No Psi EMW G1 -300 +/-50' No 135 8.7 SV6 -1205 +/-50' No 542 8.7 SV5 -1855 +/-50' No 835 8.7 Base Permafrost -1885 +/-50' No 848 8.7 SV4 -2000 +/-50' P Gas Hed atesor 900 8.7 SV3 -2525 +/-50' Poss. Free Gas or Gas H drates 1136 8.7 SV2 -2735 +/-50' Poss. Free Gas or Gas H drates 1231 8.7 SVl -3065 +/-50' Poss. Free Gas or Gas H drates 1379 8.7 Fault 1 -3435 +/- 150' M.D. (See fault section for details UG4 faulted out Thin coal UG4A faulted to -3435 +/-50' Heavy Oil between - 3435 and -3550' ss 1546 8.7 UG3 -3660 +/-50' Thin coals; Heavy oil between 3840' and 3915' SS 1647 8.7 UG1 -4145 +/-50' No, water 1865 8.7 UG_Ma -4505 +/-50' Heavy Oil between - 4505 and -4550' SS 2027 8.7 UG_Mb1 -4555 +/-50' Heavy Oil between - 4555 and -4600' SS 2050 8.7 UG_Mb2 -4610 +/-50' No, water 2075 8.7 UG_Mc -4680 +/-50' No, water 2106 8.7 SB_Na -4750 +/-50' No, water 2138 8.7 SB_Nb -4775 +/- 25' No, water 2149 8.7 SB_Nc -4805 +/- 25' No, water 2162 8.7 SB_Ne -4813 +/- 25' No, water 2166 8.7 SB_OA -4900 +/- 25' No, water 2156 8.6 SB_OBa -4950 +/- 25' Yes 2140-2180 8.4-8.6 SB_OBb -4985 +/- 25' Yes 2218 8.6 SB_OBc -5050 +/- 25' Yes 2180-2230 8.4-8.6 SB_OBd -5105 +/- 25' Yes 2160-2220 8.2-8.5 SB_OBe -5170 +/- 25' Yes 2275 8.6 SB_OBf -5215 +/- 25' Yes 2300 8.6 Base _SB_OBf -5260 +/- 25' No 2320 8.6 TD -5309 Well TD Criteria TD is 250' MD past Top OBe marker W-218i Permit Application Page 4 Well Control: 16" (if needed) and 12 '/a" holes will be drilled with diverter. The 8 3/a" intermediate hole will use well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Annular preventer will be tested to 2500 psi. Rams will be tested to 4000 psi. The BOP test frequency will be conducted on a 14 day frequency, with a function test every 7 days. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: 2438 psi C~ 5390' TVD, 8.7 ppg EMW (at TD, 10168' MD) 1899 psi C~3 surface (based on BHP and a full column of gas from TD C~ 0.10 psi/ft) • Annular Preventer 250 / 2500 psi • Rams 250 / 4000 psi • Planned completion fluid: 9.0 ppg brine / 6.8 ppg diesel (10168' MD, also TD) Kick Tolerance /Integrity Testing Summary Table Casing and Casing Test Maximum Mud Weight Exp Pore LOT / Interval Pressure Influx Press FIT Volume 95/$" Surface 3500 psi 54 BBLS 9.0 8.7 LOT Casing (assuming 10.2 LOT 7" Production 4000 psi NA NA NA NA Casin Disposal: No annular disposal in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. Variance Request: To avoid the risk of plugging the flow line with large rocks and wood encountered while ' drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line. W-2181 Permit Application Page 5 ~~ LJ W-2181 DRILL AND COMPLETE SUMMARY Pre-Rig Work: The 20" insulated conductor is installed. 1. Weld an FMC landing ring for the FMC slimhole well head on the conductor. 2. Weld on a 13-3/8" string butt-weld sub. 3. If necessary, level the pad and prepare location for rig move. Shut in nearby wells, bleed off process lines, and remove well houses as necessary Rig Operations: 1. MIRU Nabors 9ES. Nipple up diverter spool and function test diverter. 2. PU & stand back 4" DP as needed. MU 12-~/a" drilling assembly with MWD/GR. Directionally drill surface hole to the base of permafrost at 2052'. Trip for a second BHA with new bit and drill to TD at 680' below the top of the SVi . CBU, short trip to base permafrost, RIH to TD, CBS, then POOH and lay down BHA. 3. Run and cement the 9 5/8", 40.0 Ib/ft surface casing to surface with the Tesco CDS Tool, displacing cement with mud. At plug bump, test the 9 5/8" casing to 3,500 psi for 30 minutes. 4. ND diverter spool and NU and test casing/tubing head. NU BOPE and test rams C~ 4,000 psi / 250 psi, and annular to 2500 psi/ 250psi. 5. MU 8-3/a" drilling assembly with MWD/GR/Res/Azi-Den/Neu/PWD and RIH to float collar. Drill shoe track and displace to new 8.8 ppg LSND mud. Drill new formation to 20-50' below 9 5/8' shoe and perform LOT. 6. Drill ahead to production hole TD (below the base of OBf). Clean and wipe hole. POOH. 7. Change to 7" rams and test prior to running casing. 8. Run and cement the 7", 26#, L-80, BTC-M x TC-II production casing. Displace the casing with seawater, and pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7" x 9 5/8' annulus. 9. PU DPC guns and RIH w/ --160' of 4.5" Power Jet 4505 5 spf, pert guns with Anadrill LWD GR/CCL for gun correlation. 10. Once correlated correctly, circulate over to 9.0 ppg brine. Confirm cement compressive strength is at least 1,000 psi before firing. Perforate the OBa, OBc, and OBd sands. POOH LD DP and guns. 11. RU Schlumberger E-line. RIH with gauge ring and junk basket to recover any pert debris. Repeat until clean to at least 50' below the bottom perforation. 12. Run USIT/CBL log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 13. Run the 3-'/z", 9.2#, L-80, TCII completion with a 7" x 3-'h" straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TC-II threaded tubing. Top packer must be within 200' of OBa perfs. 14. Run in the lockdown screws and set the packers. Give AOGCC 24 hours notice, then test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 15. Install and test FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 16. Freeze protect the well to 2,500' TVD by pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oil truck, taking clean brine returns to surface. Allow diesel to u- tube into tubing. 17. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-'/z" annulus valve and secure the well. Assure that IA/OA are protected with two barriers. 18. Rig down and move off. W-218i Permit Application Page 6 Contingency Plan The 9-5/8" surface casing is planned to be run with a Tesco CDS Tool. If this casing running strategy does not work and a 13-3/8" second conductor string is needed, the following contingency steps will be taken. 1. PU & rack back sufficient 5" DP for 16" hole. 2. MU 16" drilling assembly with MWD/GR and drill surface hole to below the top of SV6. CBU, POOH, LD 5" DP & BHA. 3. Run and cement the 13-'/s", 68 Ib/ft casing as a two stage job providing 400' of annulus height at the shoe, then open TAM collar located at the bottom of 20" conductor C«~ 108' MD, and pump mud push followed by cement to surface. Land casing in the butt-weld sub. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. 2. Replace the DCR shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. 5. Install wellhouse and flowlines. W-2181 Permit Application Page 7 • lJ Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Tight Hole/ Lost Circulation A. Recent W Pad wells have experienced tight hole and lost circulation with drilling and running casing in Permafrost interval. Use best practices for drilling and lining surface hole interval. The Tesco CDS casing running tool will be used to address this problem for 9-5/8" casing. Contingency: A 13 3/g" second conductor will be added if the Tesco tool does not work. II. Well Control /Reservoir Pressures: Interval Psi EMW TVDss MD Schrader Bluff Sands 2156-2320 8.2-8.7 4900- 5305 9406- 10100 III. Hydrates and Shallow gas: A. Free gas and/or gas hydrates may be present in the SV5 through the SV1 surface hole below the Permafrost base. Use standard operating procedures for hydrates, if encountered. Set surface casing below deepest SV1 sand hydrate zone to isolate gas bearing intervals behind cemented pipe in surface hole from intermediate hole section. IV. Running Gravels: A. Unconsolidated sand, gravel, & cobbles and thawing permafrost could impede well angle build and casing running through permafrost. Keep moderate to low build angles until out of permafrost section. Keep flow rates low. "Obstructions" including wood and cobbles, lost circulation, and tight hole problems while drilling and running casing. See W Pad Data Sheet for details. V. Lost Circulation /Breathing: A. Possible small throw fault may be encountered in the SV1, but no faults expected in the reservoir interval. If encountered, follow LCM decision tree; reduce mudweight slightly. B. Minor pressure depletion of OBa, OBc and OBd zones produced in offset wells W-201 and W- 204 to as low as 8.2 ppg. W-2181 Permit Application Page 8 • VI. Kick Tolerance /Integrity Testing: A. The 13 3/8' cemented to surface (Contingency Plan). The 9 s/8" casing will be cemented to surface using a port collar at 1000' if necessary. The 7" casing will be cemented 1000' MD from the 9 a/$" casing shoe. B. Kick Tolerance /Integrity Testing Summary Table Casing and Casing Test Maximum Mud Weight Exp Pore LOT / Interval Pressure Influx Press FIT Volume 95/a" Surface 3500 psi 54 BBLS 9.0 8.7 LOT Casing (assuming 10.2 LOT 7" Production 4000 psi NA NA NA NA Casin VII. Heavy Oil A. Heavy oil is expected in the UG4A and M sand intervals which could result in plugging of shaker screens. Follow established operating practices for drilling in heavy oil zones. VIII. Hydrogen Sulfide A. All W Pad gas lift wells are expected to have H2S levels in the 5 to 60 ppm range; result of PBU gas lift gas H S Summa Table Well N e H2S Level m Date of Readin #1 Closest SHL Well H2S Level W-204 5 7/13/2008 fr:2 Closest SHL Well H2S Level W-201 14 7/12/2008 #1 Closest BHL Well H2S Level W-204 5 7/13/2008 #2 Closest BHL Well H2S Level W-201 14 7/12/2008 Max. Recorded H2S on Pad/Facilit W-01 A 60 8/16/2005 IX. Faults Formation Where MD TVDss Est. Throw Encounter Fault Intersect Intersect Throw Direction Uncertaint M.D. Possible Fault #1 - SVi Formation 5244' 3215' 150-180' West +/-150' X. Broaching A. Monitor adjacent wells for broaching while drilling surface or second conductor hole (if needed). CONSULT THE W PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION W-2181 Permit Application Page 9 by Schiumberger W-218 (P7) Proposal Report Date: October 27, 2008 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: Field: BP Exploration Alaska Prudhoe Ba Unit - WOA Vertical Section Azimuth: 11.350° ®~ Vertical Section Ori in: N 0.000 ft, E 0.000 ft Structure 1 Slot: W-PAD I W 218 ~ ~ O' TI TVD Reference Datum: Rotary Table Well: Plan W-218 ~OV ~j TVD Reference Elevation: 81.70 ft relative to MSL Borehole: Plan W-218 ppp Sea Bed 1 Ground Level Elevation: 53.20 ft relative to MSL UWIIAPIg: 50029 Magnetic Declination: 22.695° Survey Name 1 Date: W-218 (P7) /October 27, 2008 Total Field Strength: 57680.776 nT Tort 1 AHD I DOl 1 ERD ratio: 113.591 ° 17735.80 ft 16.21911.435 Magnetic Dip: 80.870° Grid Coordinate System: NA027 Alaska State Planes, Zone 04, US Feet Declination Date: January 10, 2009 Location LatlLong: N 70.29950252, W 149.09252397 Magnetic Declination Model: BGGM 2008 Location Grid NIE YIX: N 5959940.770 ftUS, E 612048.920 ftUS North Reference: True North Grid Convergence Angle: +Q,85436743° Total Corr Mag North a True North: +22.695° Grid Seale Factor: 0.99991426 Local Coordinates Referenced To: Well Head LJ Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Mag I Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS Kit U.UU U.UU ZtsU.UU -tll./U u.uu u.uu u.UU u.UU -- uuu u.vu oaaaa4u.rr orcu4o.ac rv ru.caaauco~ vv r4a.ua~o~oar WRP 28.50 0.00 280.00 -53.20 28.50 0.00 0.00 0.00 --- 0.00 0.00 5959940.77 612048.92 N 70.29950252 W 149.09252397 KOP Bld 1.5/100 250.00 0.00 280.00 168.30 250.00 0.00 0.00 0.00 280.OOM 0.00 0.00 5959940.77 612048.92 N 70.29950252 W 149.09252397 300.00 0.75 280.00 218.30 300.00 -0.01 0.06 -0.32 280.OOM 1.50 0.00 5959940.82 612048.60 N 70.29950268 W 149.09252658 G1 381.73 1.98 280.00 300.00 381.70 -0.05 0.39 -2.24 280.OOM 1.50 0.65 5959941.13 612046.68 N 70.29950360 W 149.09254208 400.00 2.25 280.00 318.26 399.96 -0.07 0.51 -2.90 280.OOM 1.50 0.82 5959941.24 612046.01 N 70.29950392 W 149.09254746 Crv 1.5/100 450.00 3.00 280.00 368.21 449.91 -0.12 0.91 -5.16 292.48M 1.50 1.20 5959941.60 612043.75 N 70.29950501 W 149.09256572 500.00 2.55 292.48 418.15 499.85 0.06 1.56 -7.47 328.30M 1.50 1.46 5959942.22 612041.43 N 70.29950679 W 149.09258448 600.00 2.22 328.30 518.07 599.77 1.90 4.06 -10.55 0.60M 1.50 1.79 5959944.67 612038.32 N 70.29951361 W 149.09260937 700.00 2.79 0.60 617.98 699.68 5.71 8.14 -11.54 5.40M 1.50 2.03 5959948.74 612037.26 N 70.29952476 W 149.09261739 Crv 2/100 721.20 3.00 5.40 639.15 720.85 6.77 9.21 -11.48 5.40M 1.50 2.08 5959949.81 612037.31 N 70.29952768 W 149.092 800.00 4.58 5.40 717.78 799.48 11.95 14.39 -10.99 5.40M 2.00 2.28 5959955.00 612037.72 N 70.29954184 W 149.09 296 900.00 6.58 5.40 817.30 899.00 21.61 24.07 -10.07 HS 2.00 2.53 5959964.68 612038.49 N 70.29956827 W 149.09260555 1000.00 8.58 5:40 916.42 998.12 34.73 37.19 -8.83 HS 2.00 2.76 5959977.82 612039.53 N 70.29960413 W 149.09259551 1100.00 10.58 5.40 1015.02 1096.72 51.27 53.75 -7.27 HS 2.00 2.96 5959994.40 612040.85 N 70.29964937 W 149.09258283 1200.00 12.58 5.40 1112.98 1194.68 71.23 73.73 -5.38 HS 2.00 3.14 5960014.40 612042.44 N 70.29970394 W 149.09256754 SV6 1294.65 14.47 5.40 1205.00 1286.70 93.24 95.76 -3.30 HS 2.00 3.29 5960036.46 612044.20 N 70.29976413 W 149.09255067 1300.00 14.58 5.40 1210.18 1291.88 94.57 97.10 -3.17 HS 2.00 3.30 5960037.80 612044.30 N 70.29976778 W 149.09254965 End Crv 1393.21 16.44 5.40 1300.00 1381.70 119.36 121.91 -0.83 -- 2.00 3.43 5960062.64 612046.28 N 70.29983557 W 149.09253066 13-3/8" Csg 1393.22 16.44 5.40 1300.01 1381.71 119.36 121.91 -0.83 --- 0.00 3.43 5960062.65 612046.28 N 70.29983558 W 149.09253066 Crv 1.5/100 1413.21 16.44 5.40 1319.18 1400.88 124.99 127.54 -0.29 HS 0.00 3.45 5960068.28 612046.73 N 70.29985096 W 149.09252634 1500.00 17.74 5.40 1402.13 1483.83 150.36 152.94 2.11 HS 1.50 3.55 5960093.71 612048.75 N 70.29992033 W 149.09250691 Crv 4/100 1513.21 17.94 5.40 1414.71 1496.41 154.39 156.97 2.49 HS 1.50 3.57 5960097.74 612049.07 N 70.29993134 W 149.09250382 1600.00 21.41 5.40 1496.42 1578.12 183.45 186.05 5.24 HS 4.00 3.70 5960126.86 612051.38 N 70.30001081 W 149.09248156 WeIlDesign Ver SP 2.1 Bld( doc40x_100) W-218\Plan W-218\Plan W-218\W-218 (P7) Generated 10/27/2008 12:49 PM Page 1 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS ni -' nn~~oor ~ni enn nnnne~no ~IUU.UU L~.4I ~.4U I~BZS.I/ IOOy.6/ LLL.yO LL~7.OU 0.50 rlJ Y.VV J.OJ :lAVV IVV.`4V VIGVJY:JJ IV /V. JVVIIVVJ YY IYJ.VJGYJ IGV 1800.00 29.41 5.40 1676.92 1758.62 268.74 271.43 13.31 HS 4.00 3.98 5960212.34 612058.18 N 70. 30024404 W 149.09241620 1900.00 33.41 5.40 1762.25 1843.95 320.57 323.30 18.21 HS 4.00 4.11 5960264.28 612062.31 N 70. 30038576 W 149.09237649 2000.00 37.41 5.40 1843.73 1925.43 378.19 380.98 23.66 HS 4.00 4.23 5960322.03 612066.90 N 70. 30054333 W 149.09233234 SV5 2014.24 37.98 5.40 1855.00 1936.70 386.85 389.65 24.48 HS 4.00 4.24 5960330.71 612067.59 N 70. 30056701 W 149.09232570 End Bld 2033.37 38.75 5.40 1870.00 1951.70 398.66 401.47 25.60 -- 4.00 4.26 5960342.54 612068.53 N 70. 30059931 W 149.09231665 Base Perm 2052.60 38.75 5.40 1885.00 1966.70 410.63 413.45 26.73 --- 0.00 4.28 5960354.54 612069.48 N 70. 30063205 W 149.09230748 Bld 4/100 2071.84 38.75 5.40 1900.00 1981.70 422.60 425.44 27.87 HS 0.00 4.29 5960366.54 612070.44 N 70 :30066478 W 149.09229830 2100.00 39.87 5.40 1921.79 2003.49 440.35 443.20 29.55 HS 4.00 4.32 5960384.32 612071.85 N 70. 30071331 W 149.09228470 2200.00 43.87 5.41 1996.24 2077.94 506.72 509.64 35.83 HS 4.00 4.42 5960450.84 612077.15 N 70. 30089481 W 149.0 379 SV4 2205.23 44.08 5.41 2000.00 2081.70 510.33 513.25 36.17 HS 4.00 4.43 5960454.46 612077.43 N 70. 30090469 W 149.0 02 2300.00 47.87 5.41 2065.85 2147.55 578.10 581.08 42.60 HS 4.00 4.52 5960522.37 612082.85 N 70. 30109000 W 149.09217899 2400.00 51.87 5.42 2130.28 2211.98 654.14 657.19 49.81 HS 4.00 4.61 5960598.57 612088.92 N 70. 30129791 W 149.09212055 2500.00 55.87 5.42 2189.23 2270.93 734.46 737.58 57.44 HS 4.00 4.69 5960679.06 612095.35 N 70. 30151754 W 149.09205878 2600.00 59.87 5.43 2242.40 2324.10 818.68 821.87 65.44 HS 4.00 4.78 5960763.46 612102.10 N 70. 30174782 W 149.09199396 2700.00 63.87 5.43 2289.53 2371.23 906.38 909.65 73.78 HS 4.00 4.85 5960851.34 612109.13 N 70. 30198762 W 149.09192641 2800.00 67.87 5.43 2330.40 2412.10 997.14 1000.49 82.42 HS 4.00 4.93 5960942.29 612116.41 N 70. 30223578 W 149.09185646 End Crv 2821.57 68.74 5.43 2338.37 2420.07 1017.07 1020.44 84.32 --- 4.00 4.94 5960962.26 612118.01 N 70. 30229027 W 149.09184110 SV3 3336.16 68.74 5.43 2525.00 2606.70 1494.08 1497.84 129.72 --- 0.00 5.15 5961440.25 612156.28 N 70. 30359452 W 149.09147330 SV2 3915.20 68.74 5.43 2735.00 2816.70 2030.82 2035.04 180.81 --- 0.00 5.32 5961978.10 612199.35 N 70. 30506208 W 149.09105938 Crv 4/100 4634.54 68.74 5.43 2995.88 3077.58 2697.61 2702.39 244.28 95.56R 0.00 5.47 5962646.26 612252.86 N 70. 30688522 W 149.09054510 4700.00 68.51 8.23 3019.75 3101.45 2758.37 2762.90 251.53 94.54R 4.00 5.50 5962706.87 612259.21 N 70 .30705055 W 149.09048635 4800.00 68.24 12.53 3056.62 3138.32 2851.29 2854.32 268.28 92.96R 4.00 5.54 5962798.52 612274.58 N 70 .30730028 W 149.09035069 W-218 SV1 Tgt 4822.60 68.20 13.50 3065.00 3146.70 2872.27 2874.76 273.00 95.33R 4.00 5.55 5962819.03 612279.00 N 70 .30735613 W 149.09031241 SV1 4822.62 68.20 13.50 3065.01 3146.71 2872.29 2874.78 273.01 95.33R 4.00 5.55 5962819.05 612279.01 N 70. 30735620 W 149.09031236 4900.00 67.95 16.83 3093.91 3175.61 2943.90 2944.05 291.78 94.08R 4.00 5.58 5962888.59 612296.74 N 70 .30754543 W 149.09016027 5000.00 67.72 21.14 3131.66 3213.36 3035.66 3031.60 321.89 92.46R 4.00 5.62 5962976.57 612325.54 N 70 .30778460 W 149.08991631 End Bld 5003.69 67.71 21.30 3133.06 3214.76 3039.03 3034.79 323.13 --- 4.00 5.62 5962979.77 612326.73 N 70 .30779330 W 149. 28 9-5/8" Csg 5483.40 67.71 21.30 3315.00 3396.70 3476.22 3448.34 484.35 --- 0.00 5.70 5963395.64 612481.76 N 70. 30892307 W 149.0 97 Fault Crossing 5799.80 67.71 21.30 3435.00 3516.70 3764.58 3721.10 590.69 --- 0.00 5.74 5963669.94 612584.01 N 70. 30966822 W 149.08773830 UG4A 5799.83 67.71 21.30 3435.01 3516.71 3764.60 3721.12 590.70 --- 0.00 5.74 5963669.96 612584.02 N 70. 30966828 W 149.08773822 UG3 6393.04 67.71 21.30 3660.00 3741.70 4305.24 4232.53 790.07 --- 0.00 5.81 5964184.24 612775.73 N 70. 31106535 W 149.08612249 UG1 7671.82 67.71 21.30 4145.00 4226.70 5470.68 5334.95 1219.85 --- 0.00 5.94 5965292.84 613188.98 N 70. 31407690 W 149.08263878 Crv 4/100 8127.17 67.71 21.30 4317.70 4399.40 5885.68 5727.50 1372.89 107.05E 0.00 5.98 5965687.60 613336.14 N 70 .31514925 W 149.08139805 8200.00 66.89 18.27 4345.81 4427.51 5952.13 5790.71 1395.63 105.88E 4.00 6.00 5965751.14 613357.94 N 70 .31532193 W 149.08121363 8300.00 65.85 14.05 4385.92 4467.62 6043.39 5878.67 1421.14 104.19E 4.00 6.03 5965839.46 613382.12 N 70 .31556222 W 149.08100680 8400.00 64.93 9.77 4427.58 4509.28 6134.27 5967.60 1439.91 102.41 L 4.00 6.06 5965928.65 613399.57 N 70 .31580515 W 149.08085453 8500.00 64.13 5.43 4470.60 4552.30 6224.33 6057.06 1451.85 100.54E 4.00 6.08 5966018.27 613410.18 N 70 .31604953 W 149.08075757 Ma 8578.07 63.60 2.00 4505.00 4586.70 6293.78 6126.98 1456.40 99.03E 4.00 6.10 5966088.25 613413.68 N 70. 31624056 W 149.08072062 Drp 0.5!100 8578.09 63.60 2.00 4505.01 4586.71 6293.80 6127.00 1456.40 LS 4.00 6.10 5966088.27 613413.68 N 70 .31624061 W 149.08072062 8600.00 63.49 2.00 4514.77 4596.47 6313.15 6146.60 1457.08 LS 0.50 6.10 5966107.87 613414.07 N 70 .31629416 W 149.08071504 WeIlDesign Ver SP 2.1 Bld( doc40x_100) W-218\Plan W-218\Plan W-218\W-218 (P7) Generated 10/27/2008 12:49 PM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS Mb1 Mb2 Mc Na Nb Nc Ne 8689.43 8700.00 8800.00 8809.51 8900.00 8958.92 9000.00 9100.00 9104.79 9156.08 9200.00 9217.09 9233.26 9300.00 9400.00 63.04 62.99 62.49 62.44 61.98 61.69 61.48 60.98 60.96 60.70 60.48 60.39 60.31 59.98 59.47 2.00 4555.00 4636.70 6391.96 2:00 4559.80 4641.50 6401.26 2.00 4605.60 4687.30 6488.97 2.00 4610.00 4691.70 6497.28 2.00 4652.19 4733.89 6576.28 2.01 4680.00 4761.70 6627.54 2.01 4699.55 4781.25 6663.18 2.01 4747.67 4829.37 6749.68 2.01 4750.00 4831.70 6753.81 2.01 4775.00 4856.70 6798.00 2.01 2.01 2.01 2.01 2.01 OA 9406.62 59.44 2.01 9500.00 58.97 2.01 W-218 Tgt OBa 9504.25 58.95 2.01 OBa 9504.27 58.95 2.01 OBb 9571.78 58.61 2.01 OBc W-218 Tgt OBd OBd OBe OBf Oef Base TD / 7" Csg Legal Descriation: Surface W-218 SV1 Tgt W-218 Tgt OBa W-218 Tgt OBd BHL 4878.27 4886.70 4894.70 4927.92 4978.34 4981.70 5029.51 5031.70 5031.71 5066.70 5081.43 5131.70 5134.10 5186.70 5186.71 6835.75 6850.42 6864.29 6921.40 7006.62 7012.24 7091.40 7094.99 7095.01 7151.98 7175.73 7255.81 7259.60 7341.74 7341.76 6226.42 1459.87 LS 0.50 6235.84 1460.20 LS 0.50 6324.67 1463.31 LS 0.50 6333.10 1463.60 LS 0.50 6413.11 1466.40 LS 0.50 6465.02 1468.22 6501.13 1469.48 6588.73 1472.55 6592.92 1472.70 6637.67 1474.27 6675.91 6690.77 6704.81 6762.65 6848.96 6854.66 6934.83 6938.47 6938.49 6996.18 1475.61 1476.13 1476.62 1478.65 1481.68 1481.88 1484.70 1484.83 1484.83 1486.86 7020.24 7101.35 7105.19 7188.39 7188.41 LS LS LS LS LS LS LS LS LS LS 0.50 0.50 0.50 0.50 0.50 0.50 0.50 0.50 0.50 0.50 6.11 5966187.72 6.11 5966197.14 6.12 5966286.00 6.12 5966294.43 6.13 5966374.46 6.13 5966426.40 6.14 5966462.51 6.14 5966550.15 6.14 5966554.34 6.15 5966599.11 6.15 5966637.35 6.15 5966652.21 6.15 5966666.26 6.16 5966724.13 6.17 5966810.46 LS 0.50 6.17 5966816.16 LS 0.50 6.17 5966896.35 HS 0.50 6.17 5966900.00 179.01 L 0.50 6.17 5966900.01 179.01 L 0.50 6.18 5966957.73 613415.67 N 70.31651222 W 149.08069231 613415.86 N 70.31653794 W 149.08068963 613417.64 N 70.31678064 W 149.08066431 613417.81 N 70.31680365 W 149.08066191 613419.41 N 70.31702222 W 149.08063910 613420.46 N 70.31716405 W 149.08062428 613421.18 N 70.31726269 W 149.08061398 613422.94 N 70.31750201 W 149.08058896 613423.03 N 70.31751345 W 149.08058777 613423.93 N 70.31763572 W 149.0498 613424.70 N 70.31774017 W 149.0 405 613425.00 N 70.31778076 W 149.08055980 613425.28 N 70.31781913 W 149.08055578 613426.45 N 70.31797715 W 149.08053924 613428.19 N 70.31821294 W 149.08051453 613428.31 N 70.31822850 W 149.08051290 613429.93 N 70.31844751 W 149.08048994 613430.00 N 70.31845746 W 149.08048890 613430.00 N 70.31845751 W 149.08048889 613431.17 N 70.31861513 W 149.08047239 1487.70 179.01 L 0.50 6.18 5966981.79 613431.65 N 70.31868085 W 149.08046552 1490.53 179.00E 0.50 6.19 5967062.94 613433.27 N 70.31890245 W 149.08044244 1490.66 179.00E 0.50 6.19 5967066.77 613433.35 N 70.31891292 W 149.08044136 1493.55 LS 0.50 6.20 5967150.00 613435.00 N 70.31914022 W 149.08041781 1493.55 LS 0.50 6.20 5967150.01 613435.00 N 70.31914026 W 149.08041781 5187 .52 7343.01 7189.67 1493.59 LS 0.50 5241 .68 7425.95 7273.69 1496.50 LS 0.50 5251 .70 7441.13 7289.06 1497.04 LS 0.50 5251. 71 7441.14 7289.07 1497.04 LS 0.50 5296 .57 7508.43 7357.23 1499.40 LS 0.50 5296. 70 7508.62 7357.42 1499.40 LS 0.50 5341. 70 7575.08 7424.74 1501.73 LS 0.50 5352 .19 7590.43 7440.28 1502.27 LS 0.50 5390 .62 7646.20 7496.78 1504.23 --- 0.50 Northing (Y) fftUSl Easting tXl fftUSl 5959940.77 612048.92 5962819.03 612279.00 5966900.00 613430.00 5967150.00 613435.00 5967458.48 613441.07 6.20 5967151.28 6.20 5967235.32 6.20 5967250.70 6.20 5967250.71 6.21 5967318.89 6.21 5967319.09 6.21 5967386.43 6.22 5967401.97 6.22 5967458.48 613435.02 613436.68 613436.98 613436.98 613438.32 613438.33 613439.65 613439.96 613441.07 N 70.31914373 W 149.08041745 N 70.31937325 W 149.08039373 N 70.31941524 W 149. 939 N 70.31941528 W 149.0 39 N 70.31960146 W 149.08037015 N 70.31960200 W 149.08037009 N 70.31978591 W 149.08035109 N 70.31982837 W 149.08034670 N 70.31998270 W 149.08033076 WeIlDesign Ver SP 2.1 Bld( doc40x_100) W-218\Plan W-218\Plan W-218\W-218 (P7) Generated 10/27/2008 12:49 PM Page 3 of 3 9600.00 9695.47 9700.00 9798.48 9798.49 9800.00 9900.00 9918.36 9918.37 10000.00 10000.24 10081.25 10100.00 4796.57 4805.00 4813.00 4846.22 4896.64 4900.00 4947.81 4950.00 4950.01 4985.00 4999.73 5050.00 5052.40 5105.00 5105.01 5105.82 5159.98 5170.00 5170.01 5214.87 5215.00 5260.00 5270.49 10168.36 55.62 1.98 5308.92 4963 FSL 1175 FEL S21 T11N R12E UM 2558 FSL 895 FEL S16 T11 N R12E UM 1342 FSL 4954 FEL S10 T11 N R12E UM 1592 FSL 4945 FEL S10 T11 N R12E UM 1900 FSL 4934 FEL S10 T11N R12E UM 58.47 57.99 57.96 57.47 57.47 57.46 56.96 56.87 56.87 56.46 56.46 56.05 55.96 2.00 1.99 1.99 1.98 1.98 1.98 1.98 1.98 1.98 1.98 1.98 1.98 1.98 by Schlumberger WELL FIELD STRUCTURE W-218 (P7) Prudhoe Bay Unit - WOA W-PAD Magnetic Parameters Suelace LowUOn NA02J Rlaska State Ptanes. Zone 04, US Feei Miscellaneous McOel: BGGM 2008 Op: 80.8)0° Date'. January 10, 2009 Lat'. NT0115B.209 No~bing: 5959900 ]] ftUS GnE DonV: •08543fii43° Slol: W 118 NO Rel'. Rotary Table X81 ]0 M above MSL7 Mag Dec: •21 fi95° FS: 5>fi80B nT Lon: W149533086 EasUng: 6t 100892 BUS Style Fast-0.9999142821 Plan W~218 (P)) Srvy Date'. October 2], 2008 0 1000 2000 3000 4000 5000 6000 7000 8000 0 1000 2000 x O O O C 3000 H 4000 5000 Enf crv aloo W-218 SW ._..r..-.._..-.._.._..-..-.._.~_.. _..-.._.._..-..-.._..-i.-..-..-..-..-..-..-..-..y. _..-.._.._..-.._..-..- 5g..._.._..-.._.._.._..-..- _.._..-..-.._..-..-..-..- -..-..-..-..-..-..-..-. ~ -..-..-..-..-..-..-..- /Fadlt Crossing •t- -t•- RTE WRP ~KOP Bld 1.51100 _.. _.. _.. _.. _.. _.. _.. _~. _.. _.. _.. _.. _.. _.. _.. _.. y..-..-..-..-..-..-..-..-.. j..-..-..-..-..-..-..-..-..~..-..-..-..-..-..-..-..-.~_..-.. _.._.._..-..-..-.._~.-..-..-..-..-..-..-..-..->.-..-..-..-..-..-..-. Crv 1.51100 Crv 21100 End Crv 13-318" Csg ~ -_ ._.._.._)._.._.._.._.._.._.._.._..y..-..-..-..-..-..-..-..-..j..-..-..-..-..-..-..-..-..j...-..-..-..-..-..-..-..-.j-..-..-..-..-..-..-..-..- -..-..-..-..-..-..-..-. ..-..-..-..-..-..-..- ~! Crv 1.51100 t~ .y.- Crv 41100 End Bld : Bld a100 ... ~. a tsemr : -.. -j: -.. -.. '.. -.. -.. -.. ~.. - . ...............................~::.... ~........................ ': ~:......... ~.......... ~....... ...............................~................................~:................ ~.. ~.. ~.... .... 0 1000 2000 3000 4000 5000 6000 7000 8000 Vertical Section (ft) Azim = 11.35°, Scale = 1(in):1000(ft) Origin = 0 N/-S, 0 E/-V 1000 '000 3000 • 1000 i000 by • • Schlumherger WELL W-218 (P7) FIELD Prudhoe Bay Unit - WOA STRUCTURE W-PAD Magneto Parameters Surtace L ocatbn NAD2] Flaska SiMe Planes. Zone 00. US Feel Miscella reous Motlel: BGGM 2008 Dip: 80.8]0° Dale nuary t0. 2009 Lat. N]01]SB.209 rMing: 6959940.]]RUS Gritl GOnv+0.85x38]43° Sbt'. W-218 NDRei. Diary Table fi']Cflabove MSL) Mag Dec: +22.695° F5: 5]680.8 nT Lon: Wtx95J3086 Easfing: 6120x892 M15 Srale Fact: 099991x2822 Plan: W~218 (P]) sm Date: oaobar z].2o6e -2000 -1000 0 1000 2000 3000 7000 6000 5000 n n Z 0 o aooo C N 03 U ~ 3000 v v V 2000 1000 Tl1l 7" Cs 19 (P7) W-218 T¢ OBd N ..j ..................................j..................................~........................1M-778~Tyt Oga........ .................j............... ......... Drp 051100 ..i .................................. j..................................:.................................. ~.................................j.................................. j.............. Crvi41100 ...................................:.................................. t.................................; ..................................}..................................;.............. Fault Crossin 9318" Cs End:Bld ...........................................................j..................................:.............. ..:..................................o....................Vv=318'§~iYgt .... . crv aloD W-218 SV1: Flt 3425ss ..:..................................:..................................:..... ...........................~..................................j..................................:.............. End Crv Bld x100 End Bld crv aloo cry l.s~loo 133111" Cs End Crv Crv 21100 KOP Bld 1.51100 ..y .................................. j........................... .............................,.................................. j .................................. j.............., Crv 1.51100 RTE -2000 -1000 0 1000 2000 3000 c« W Scale = 1(in):1000(ft) E »> 7000 6000 5000 4000 3000 2000 1000 n Field: Prudhoe Ba}- • Site: PB W Pad Well: Plan W-218 Wellpath: Plan W-218 II i,,l ~~~0 ~~ ~0 2 n n ~0 SEC 16 SEC 21 ~_ w N 2414.5 - - - ^ - m N N , W ... ,-..~~ N 2904 ~ ~~ I N 2822------.- W-2181 '_. ~ W-2171 ^ 201 -_____________ ^ 200 ^ 24 ~~ ^ 23 ^ 22 ^ 21 I' . 20 33^ ^ 19 32^ ^ 18 31^ ^17 ^ 16 ^ ~~i 30 29 ^ '~ ^ 15 211 ^ • 14 27^ • 212 2s^ ^210~ ^ 215 L o 25^ ~~ ^207 n N I W ~ ~~ 11209 ~ *yl 1 W '~ I 2 34 ' 3 35 ~ I~~ 4 36i +5 I III 37 ~ 7 38 g 39* ~g ~~ I 40 ~ ~ 9 400 ~ i ~I 10 42 + ~ ~I 11 45 ' ^ 12 44 ~i } 205 j 203 I~~ rn ~W ~°~ LEGEND -~ AS-BUILT CONDUCTOR ^ EXISTING CONDUCTOR NOTES: 16 ST END N0.1 21 f KUPAAUK S j NO.'N~1. ~_, ~ ( ~ ~~ 15 22 tsYASmc ABEn ~ VICINITY MAP N.T.S. OF ~E °° q *~°49 ~- °9~ , oo°oo°oooaao°oo aooo°°°°°°o°o °a °°° Richard F. Allison ~s °° ao 10608 _'"~ESSIONA~ ~' SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS-BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF SEPTEMBER 23, 2008 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD27. 2. BASIS OF LOCATION IS W PAD MONUMENTS W-1 & W-2. 3. BASIS OF ELEVATION IS W PAD MONUMENT W-2. ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 4. GEODETIC POSITIONS ARE NAD27. 5. PAD MEAN SCALE FACTOR IS 0.99991420. 6. DATE OF SURVEY: SEPTEMBER 23, 2008. 7. REFERENCE FIELD BOOK: W008-18 PGS. 22-24. LOCATED WITHIN PROTRACTED SECTION 21, T. 11 N., R. 12 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS W-217i Y= 5,959,925.86 N= 2,731.92 70°17'58.062" 70.2994617° 2' 53 4,949' FSL ' X= 612,049.02 E= 2130.01 149°05'33.090" 149.0925250° . FEL 1,175 W-218i Y= 5,959,940.77 N= 2746.83 70°17'58.209" 70.2995025° 2' 53 4,964' FSL ' X= 612,048.92 E= 2129.91 149°05'33.086" 149.0925239° . FEL 1,175 F. Robert °"AW"' BARNHART (~1 CHECKED' ~ MANSER /°~ N O ~~ Jn ~~~ DATE: 9~24~09 U DRAWING: FRBOS WOW 05-00 WOA W-PAD sHEET: DB No ~ ~~~OO ~o AS-BUILT CONDUCTOR 0 9 24 08 ISSUED FOR INFORMATON lF8 SPM SCALE: WELLS W-217i & W-2181 1 of 1 N0. DATE REVISION BY CHK 1"=300 ~_ C~ d Cn Q -N- W-PAD • Oilfield Services, Alaska Schlumberger Drilling & Measurements 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Monday, October 27, 2008 Garret Staudinger BP Exploration (Alaska) Inc. i SchN~mbe~er Prudhoe Bay W-218 (P7) Nabors 9ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two hundred feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Program: Instrument Type Start Depth End Depth GYD GC SS 28.50' and 1000.00' and MWD + IFR + MS 1000.00' and 10168.36' and Close Approach Analysis results: Under method (2), note. All drilled wells pass major risk. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drilling Aids to be provided: A drilling map and traveling cylinder will be provided. n R m ~' Checked by: Scott DeLapp 10/27/2008 ' 'Company: BP Amoco Dute: 10J27/2008 Time: 12:31:51 Page: 1 Field: Prudhoe Bay f Sit PB W P d ' d rdinate C W-218 Tr ) Reference: Well: Plan NF ue North --- erence e: a e ~ oa~ . , ( , I Reference Well: Plan W-218 Vertical (TV D) Reference: W-218 Plan 81.7 ~I Reference Wellpath: Plan W-218 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are IO~t~Ifliaeells in thisftt~dlpal Plan & PLANNED PROGRAM i Interpolation Method: MD IntervaL• 5.00 ft Error Model: ISCWSA Ellipse -De~tir Range: - 28~(~ o Maximum Radius: 1213.99 ft _ -~1V1-ethod~ ~Tav eylindar 9o Error Surface: Elli se + Casin rt~ _. ~ i~ -_ __ Survey Program for Definitive Wellpath ! Date: 3/20/2008 Validated: No Version: 6 -- I P-fanned-Erou~-'ro-- --Survey __- -_ - --_ T....~„a,. ---- wool-Name -__ ----- ft ft - - 28.50 1000.00 -_ Planned_ Plan #7 W-218 V1 _ -___- GYD-GC-S$ __ G~rodata gyro single shots -_- _ __ ~ 1000.00 1393.00 Planned: P lan #7 W-218 V1 MWD+IFR +MS MWD +IFR + Multi Station I 1393.00 5483.00 Planned: P lan #7 W-218 V1 MWD+IFR+MS MWD +IFR + Multi Station --54800- 19'F68.36 P+awned:-Rtan#7-VV-248~/'~- - - -RhW8+4FR+AAS-- ~"~n.~+ IFR-+Mult~Statiorr- - - --- - Casing Points _ - -- - - - MD "rVD Diameter Hole Siie Name ft ft in in r 1393.21 1381.70 13.375 16.000 13 3/8" II 5483.40 3396.70 9.625 12.250 9 5/8" ------ ~'F046~36589~6~-000 _ --~~~58 ~ _ - - Summary <~----- Offset Wellpath > Reference Offset Ctr-Ctr No-Go Allowable li Site Well Wellpath MD MD Distance Area Deviation Warning - ~°- ft ft ft ft PB W Pad Plan W-202 Plan W-202 OBd V4 Plan 458.61 460.00 122.00 8.95 113.05 Pass: Major Risk -- t1~6-V1~Pad- - -Klan W-20~ ~lan-W 202L'Fti,_°c~/2 W ~58.61 -_ 4680- 12:00 X95 113:05- Kass: Majo~Ri.>k ____ PB W Pad Plan W-202 Plan W-202L2 OBa V1 PI 458.61 460.00 122.00 9.12 112.88 Pass: Major Risk PB W Pad Plan W-217 Plan W-217 V5 Plan: PI 554.36 555.00 14.94 10.48 4.46 Pass: Major Risk PB W Pad Plan W-219 Plan W-219 V2 Plan: PI 419.10 420.00 153.98 8.22 145.76 Pass: Major Risk PB W Pad Plan W-220 Plan W-220 V3 Plan: PI 543.06 545.00 43.02 10.05 32.98 Pass: Major Risk i PB W Pad Plan W-2xxai Plan W-2xxai V1 Plan: .374.83 375.00 15.79 ._7.39 8.40 __- Pass: Major Risk _ - _ PB W Pad Plan W-2xxbi Plan W-2xxbi V1 Plan: 628.41 630.00 28.70 11.29 17.42 Pass: Major Risk PB W Pad W-200 W-200 V2 471.43 475.00 171.09 8.47 162.62 Pass: Major Risk B-W Pad- W-2~0 - W-280R8~1-'~ - - 47,^~3 4x5.00 'I X1-09 -- 8~',1 ~G~62--- °ass: "~ajer RislF- PB WPad W-201 Plan W-201A V1 Plan: P 379.53 380.00 136.35 6.64 129.71 Pass: Major Risk PB W Pad W-201 W-201 V4 379.53 380.00 136.35 6.64 129.71 Pass: Major Risk - - PAW Pa - - - W=204 V2 -354:62 T4~~IOO~T4 -355:Q~T07-63 _ )o`Rr is ~ass~: Vl-a -_ _. ~~ PB W Pad W-204 W-204L1 V6 354.62 355.00 107.63 7.48 100.14 Pass: Major Risk PB W Pad W-204 W-204L2 V6 354.62 355.00 107.63 7.48 100.14 Pass: Major Risk PB W Pad W-204 W-204P61 V2 354.62 355.00 107.63 7.48 100.14 Pass: Major Risk ~, I PB W Pad W-213 W-213 V13 548.08 550.00 89.63 9.85 79.78 Pass: Major Risk '~, - - -PB V~Rad ~1V-244- - ~!V-~44V~6- _ ~~-.^^.'6 4000- 76:46 €~24 68:1- Ras~R~ajor ~;.>k PB W Pad W-216 W-216 V7 854.46 860.00 51.18 15.15 36.03 Pass: Major Risk PB W Pad W-23 W-23 V5 530.72 545.00 243.45 12.24 231.21 Pass: Major Risk - Pl3 Wpaif -_~lV=Z3-- - - ~1t1=~3FCVS -- - 529.03 _535~Ofi--..2-'43.-4~T2~Z0 -- 231.-2~ Pass Major id's c~_ - --- ! PB W Pad W-24 W-24 V2 501.07 505.00 206.89 9.16 197.73 Pass: Major Risk I~ FieldPrudhoe Bay Site PB W Pad We11:Plan W-218 WellpathPlan W-218 From Surface - TD -Scan interval lOQ ft Scale 1:50 -1 5 6 150 100 50 o z 50 100 150 -2xxai) -217 (PI ! '-?a~M (Plan N'-2t< -21s (w- Ian W-22 o2t.osega Travelling Cylinder Azimuth (TfO+AZI) (deg] vs Centre ~~~~_L~~ rte: PB W ~a - - - - - an - T7,Plan V~2TS Dn i~rget ~onf: o - - sedori: Prnned-Program escnphon: ertica ept a ow can ea eve __ a~fiing 596690~~O~~t ~I +NT ~b~3$~4b ff ap- ~ - - - - -- - ---- - atitu e: ongitu e: Shape: arc e a ms: ~, ~' - ~~~n - i~ - _- - _ -- Site: P~ ~~ __ - _ - an - - - - - T~~ argef ~on~. _ - c on: anne rogram escnphon: ertica ept a ow can ea eve - - - __- ~Noi-thing:39b7I3600~ _.__-- --- -ZocaI+N7=571$ff:38 t~ _--- -- -- - _ - -_ ___ _ -- --- Ica --- - ahtu e: ongdu e: -_ Shape: arc e _ _-_ - -- _ -- _ - _ Radius: 1 d~ R 11\GL LHEAD = FMC CTUATOR = 3aker Hydraulic . ELEV = F.•ELEV = OP = 300' Angle = 69 deg mMD= tum TV D = 41/2" TBG, 12.6J~, L-80, TG11, .0152 bpf, ID= 3.958" W 21 'Proposed JMrG11 IR/1 W. I7W PM `W 00/J N rVLL 1V R~EASE" BUT CAN ALSO BE RB.EAS® BY PRESSURE DO~t7CC®4300 PSI. TEST PRESSUREPIU2 RO = 5d1R PRI ld4A9 PRI IR Rf1aL f1F PKR RATINP.I"** \j 29' H4v2" XO 3-1/2", ID = 2.992" ~~ 29' 3027' 3-1/2" HES X NIP, ID = 2.813" GAS LIFT MANDR~ 6 9338 MMG DCR RK WATER INJECTION MANDRELS ~ 9-5/8" CSG, 40#, L-80, BTC, ID = 8.835" ~~ 6483 T' CSG, 261F, L-80, TC-11, .0383 bpf, ID = 6.276" -{- Minimum ID = 2.75" ~ 9884' 3-1/2" HES XN NIPPLE MARKER JOINT w / RA TAG -~ DA 93; ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 9438 MMG-W DMY RK 4 9547 MMGW DMY RK 3 96'66 MMG-W DMY RK 2 9735 MMGW DMY RK 1 9823 MMG-W DMY RK 9368' ~-{ 3-1/2" HES X NIP, ID = 2.813" 9399' ~ T' HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920" 9412' NOPG Pressure Gauge MARKER JOINTw! RA TAG REF LOG: SLB Realtime LWD ANGLEAT TOP PERF: Note: Refer to Ftoduction DB for historical pert data SIZE SPF INTERVAL OpNSgz DATE 41/2" 5 Oba xxxx'-xxxx' O 41/7' S Obc xxxx'-xxxx' 0 41/7' S Obd xxxx'-xxxx' O ~NDPG Pressure Gauge ~3-1/2" TBG, 9.2#, L-80, TC-II, .0087 bpf, ID = 2.992" PBTD T' CSG, 26#, L-80, BTGM, .0383 bpf, ID = 6.276 I 9906' I 10168' T' HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920" 9589' H NDPG Pressure Gauge 9636' 3-1/2" HES X NIP, ID = 2.813" 9764' ~-{ 7" HES A HR PKR w / 1/4" FEED THRU, ID = 2.920" 9802' H3-1/2" HES X NIP, ID = 2.813" 862' 3-112" HES X NIP, ID = 2.813" 9884' 3-1/2" HES XN NIP, ID= 2.75" 9906' {-i 3-1/2" WLEG, ID = 2.992" DATE REV BY COM1MIENTS DATE REV BY COMMENTS 08/13/08 GJS Proposed WBD (tNP7) ORION UNfT WELL: V1~218i PERMfT No: xxxxx API No: 50-029-xxxxx Sec, Tw p, Rge BP 6cploration (Alaska) •I i 5900000 ~-- 5850000 ~-- 400000 500000 40 CFR 147.102 b 3 600000 700000 800000 •i Alaska Department of Natural Resources Land Administration System Page 1 of~ { • ;~.5k " :~~_~ -._ ~_i .. , -;~ ~ ~~.~ R2corder'~ Search State Cabins ~1~#tli~8 R~S~DiIS ~" File Type ADL File Number 28261? °~- Printable Case File Summary See Township, Range, Section and Acreage? New search ~` Yes No _.._._~. ~ . __ _._... I.,AS Mena ~ Case Abstract ~ Case Detait i Land Abstract I~'rle: ADL .x.8261 '~`'~"` Search for Status Plat Updates ;1 ref (1'O6%~OOS Custorne~°: 000107377 BP EXPLORATION (ALASKA) INC PO E3OX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995 1 9661 2 Case 7Vpe: 7~ OIL & GAS LEASE COMP DNRUnit: 780 OIL AND GAS File Location: DOG D[V OIL AND GAS Case Status: 35 ISSUED Status Date: 0811 ]/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Pt°intar~~ Respo~lsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/0}/2006 Case Suhtyhe : i~S NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED llc°rr~/rrnr.~ ['; I'awrzship: O11N Range: 012E Section: Q ';,-s S~c~~u~1f7Acres: 6~0 aearoh ~Ie7Yc~lo11.~ ~ ~ ~OW72Sj71~J: 01 IN Range: O ~ ~~ .~cCf1o11.~ O~ :~c-'C"I!(IYI .~ICPC.~': v~0 Vt~rirGu~r.~ l' Totivnship: O11N Range: 012E 5~~~~lion.~ (i~~ ti~<~~~rion.lcres:640 lt~~~~idrun.~ [; loirn~6tip: OllN Range: (?12E Section. I(i .~r~cirort.9cres:64U Leta! I?eseription 0 ~-?~Y-196 ~ ^` ~` *SALE NOTICE LEGAL DESCRlPT1O:V C'1 -1- 56 IIN 1?E UNI3,-t, 9,10 260.00 0-1-01-19 "~*** UNIt17.F7) LF_G:iL DF.SC,'RIPTION*** PRL'DHOE BAY UNIT TR.9CT 48 http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28261 &... 11 /6/2008 Alaska Department of Natural Resources Land Administration System Page 1 of ~ ~ • 4 ac;:.~ Lt : ,,t - .ar,~~ .~..cr :,_. air; F,~ Border's Search State Cabins ~~tli~~ S+D41CCes w ~ .......... I,i File Type ADL_._,.... File Number: 2$263 ~+ Printable Case Fi.t...e. Summa._ry See Township, Range, Section and Acreage? _._ W I Yes ~ NO ~ New Search ~.AS lUIF!nF~ ~ Case Abstract ~ Case ©etail ~ Land Abstract ~. file: aUL 28263 ~'''~'~' Search for Status Plat ~Jpdates ~s cif I ]i06/?UUti Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Tape: 784 OTL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Dute: 08/I 1/1965 TotalAcres: 2560.000 Date h~itiate~L~ 05/28/1965 Office of Prin7ary Responsibility: DOG DIV OIL AND GAS Lust Ti•ansactian Date: 12/04/2006 Case Subtl>pe : t~~ NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED lh>>~icliur~~ U Trnrnslu~~: U I ~N R~r~r~~<~.~ Ol '1~: .~'ectivn: l ~ S'c~ctiojt _lcrrs.~ 640 Searciz Plats ,llc~ri~lr~nr.~ U /uic~~t~ht~~: O1 1N Range: U I ~E S'~~c~lr~,n: I h .ti's-~-Muir .~l~~rc~.r: (i-1O al~t•r~lr~irr. l~ /~~ticf~~~/1rJ~: O11N Range: OI2E .~'~~cliurr.~ 21 .ti'cctru~r 1c~res: (i-~l) I~~ric/ru~t' U To~~tshr~~.~ (ll l V' Rafzge: 012E ,~'~~~~~iuj~. ~'~ .5~r~c~[inn.lcr~~s: 6->0 Legal D!escr•ipiion OS-28-1965 * * * SAI F_ NOTICE LEGAL DESCRIPTION ~ ~` C1-1-~9 TIIN, R12E, UM1~, 16, 21, 22 260.00 11-?8-19<9 SEGMENT I T 11 N, R 12E, UM http://www.dnr. state.ak.us/las/Case.Summary.cfm?FileType=ADL&FileNumber=28263 &... 11 /6/2008 TRANSMITTAL LETTER CHECKLIST WELL NAME _ ,~~ j.~/--~/~ Development ,~ Service Exploratory Stratigraphic Test Non-Conventional WeU `~ ~4 FIELD: ~ DyD POOL: f~OL/7iG~~/S ~IL Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter Cf~CK ADD-ONS WHAT (OPTIONS) ~~ FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits API number in permit No. . AP[ No. 50- 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 togs acquired for well SPACING The permit is approved subject to full compliance with ZO AAC EXCEPTION 25.055. Approval to perforate and produce / in',Ig~t is contingept 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 i 0' sample intervals throu h et zones. Non-Conventional Well please note the following special condition of this permit: production or production testing of coal bed mejhane is not allowed for (Warne of weU) until after Cora~anv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~Comnanv Name) must contact the Commission to obtain advance approval of such water wet! testing ro Rw: u~ moos IfV~LL PERMIT CMECKLI$T Pield 8 Pool PRUDHOE BAY, POLARIS OIL - 640160 Well Name: PRUDHOE BAY UN POL W-218 Program SER We11 bore seg ^ PTD#; 2081740 Company BP EXPLORATION~ALASKA) INC Inhial Classffype SER I PEND GeoArea 890 Unit 11650 OnlOff Shore On Annular Disposal ^ Administration 1 Permitfaeattached-- -- --- --- --- - --- --- -- - NA-- ---- - - --- - -- - - ---- --- ---- - --- --- --- 2 lassenumbarappropriate---- - - -- --- -- -- - -- -- Yes- --- -- - ---- -- - ---- ---- -- -- -- - --- 3 Uniquawell-name and number-- -- -- - --- -- - - -- - Yes -- --- -- -- -- ----- - - -- - - -- - - -- - 4 Well located tn.adefinedpool----- --- - - -- - - --- -- Yes - -- -?°IarisPOOI. --- - --- -- ------ -- - - -- --- 5 WeIIIQCatedproperdistanceiromdrillingunit_boundary_______________ ________Yes_---.- --------------------------- ------------------------------------------ 6 Well located DroRar distance from other wells- - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 SutfiCiQntacreAge_ayailahleindritlingunit_______-__-___-__-__- -___ -_--Yes------ -2560 acres•________________----------------------- -- - -- - 8 If deviated, is_wallbora platincluded - - - - - - - - - - - - _ Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9 Operator°nlyaffectedparty --- --- -- -~ --- - - ------ Yes- --- - -- -- -- --- ---- ----- -- - - --- ---- --- 10 Operalorhas-appropriate bond in force------------------------ --------Yes.__-.- -Blanket@ond#6194183..------------------._----------------------------- 11 Pe[m~caD be issued wfthout ~Anst<rvati°n Order - - - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 12 Pe[mitcanbeissuedwithoutadminist[ativ_e_approVal--------------- ---------Yes----- ------------------------------------ -- --- -- - - --- 13 CanpermttbeaRplQVedbef4re15-daywait----------------- -- ----Yes------ -- ------------------------------------ - -- -- ---- --- ACS 1116/2008 14 Well located within area and_strataauthorized by-Injeciion Order fE (put1O# in_comments)_(Fgr_ Yes - - _ - _ _ _ A1O.25-(tnjectian of fluids for enhanced_recovary),- _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 All wells-wfthtn 1!4_mile area of review identified (for service well only)- - - - - - - - - - - - - - Yes - _ _ - - - _ W-204 {fluids injection will support-production from well).- _ - - - _ _ . _ _ - _ _ - - _ _ _ _ _ _ - - _ - - _ - . _ - - 16 Pre-Rroduced injector, duration of Pre-production tesa than 3 months_{for service wel(only) - - -NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 ~lonconyen, gas_confOrms to AS31,05,030(j,1.A)~(1.2.A-D) - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 Conducto[ sting-provided - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - 19 Surface_casir~9-proteotsall-knOwnUSDWS---------------------- --------- NA------- -Allaquifersexempted,-AEO1.------------------------------------------------ 20 CMT-votadequate.tooircutate_onconductor&surfcsg--------------- ---------Yes------ -------------------------------------- --- - -- - - ---- 21 CMT-voladequate_t4tie•in long string to surf cs-g--------------- - --------- NO---- -- -- --- - --- ----- --- - -- - - --- - -- 22 CMT_will cover all known-productbe horizons- - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 23 CasingdasgnsadequataforC,TB&_permafrost------------------ --- ----Yes----- --------------------------------------- --- -- - - --- -- 24 Adequate tankageor reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ - _ - - - _ Rig equipped with steel pits. No reserve pit planned•_All wasietoapproved disRosal well(s)< - _ - _ _ . _ - _ - 25 Ifa_re•drill,bas_a10.403forabandonment been approved------------- --------- ~------ --------- - - -- ---- ---- ---- -- -- - ~ -- ----- 26 Adequate wehpote separationproposed_ _ _ - _ - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ Proximi-ty anaysis performed, Traveling cylinder path calculated, Gyros likely-in surface hole. - - _ _ _ - - - - _ _ _ 27 Ifdlvertarraqutrad,d2esitmeetregulations--------------------- ---__----Yes----- ------------------------------------------ -- --- ---- ----- Appr Date 28 Drilling fluid_program schematic & equip list adequate- - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ - _ Maximum expected formation pressure 8,7_EMW._ MW planned up to 9,5-ppg in_surface hale and 9.0 ppg in zone. TEM 1111212008 29 BOPJrs,dotheymeetregulation--- - --- -- - - -- - --- --Y~-- - --- -- ---- -- -- - - ---- ------ ~ --- -- --- 30 BOPS-press rating appropriate; test to_(put prig incomments)- - - - - - - - - - - - - - - - Yes _ _ _ _ - - MASP calculated at 1898 psi. 4000_psi_BOP testplar>nad, _ _ _ - _ _ _ - - _ _ - - _ - _ _ _ - - - - - _ - - - _ _ _ /;~/ 31 Choke-manifold compGeswlAPl_RP-53 (May 84) - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - I* 32 Work will occur wikhout operation shuidown- - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is presence-of H2S gas probable - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ - - - _ H2$ is reported-at W pad_ Mud shouldprecl_ude H2& on rig Rig has sensors and alarms.- - - - - - - _ _ _ - - - - _ 34 Mechanical condition of walls within AOR verified (Forservlce well only _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ - Wr204 only welt in AOR, No known_integrity_issuQS. _ . - - _ _ _ _ . _ - _ _ - _ _ _ _ - - - _ - - _ _ - - - - _ - Geology 35 Pemlitcan be issued w1o hydrogen sulfide measures- - _ _ _ - _ . _ - - _ _ - - - - _ _ - . _ - No_ _ . _ _ _ .Max level H2$ on Wpad is 60ppm ortwell IAr-01A (8!16104)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 36 DataprasentQdonRotantialoverpressurez°nes- ---- -- - -- -- -- - ~- --- - -- -- ----- ----- ------------ -- --- -- - --- Appr Date 37 SetsmicanblYsisofshalbwgas_zo[~s------ ---- - -- -- - ---- --~A --- --~- --- - - ----- ------ ---- -- --- --- ACS 111612008 38 Seabedcondiifonsurvay-(if4tfshore)----------------------- ----------~------ ---- - - -- - -- ----- --- 39 Contact nameiphonefnrweakly-progress repods (exploratory only] _ _ - - - _ _ _ _ _ _ _ - _ Yes - . _ - - _ _ Garret $taudinge[ - 564-4242_ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ - - _ _ _ _ _ _ _ - - _ - _ - . - Geologic Commissioner. Engineering Public Date' Commissioner: Date Co i r Date ~~~ «~~ ~ /l ~3-08 U
