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201-060
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, October 16, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-31 NORTHSTAR UNIT NS-31 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2023 NS-31 50-029-23009-00-00 201-060-0 G SPT 10578 2010600 2644 4566 4571 4571 4574 257 387 377 377 4YRTST P Brian Bixby 8/25/2023 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:NORTHSTAR UNIT NS-31 Inspection Date: Tubing OA Packer Depth 1498 2932 2909 2909IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230826041301 BBL Pumped:2 BBL Returned:2 Monday, October 16, 2023 Page 1 of 1 MEMORANDUM State of Alaska Permit Number: 201-060-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg V11 DATE: Monday, August 12, 2019 ,} P.1. Supervisor 114-'Icl SUBJECT: Mechanical Integrity Tests Packer Depth Pretest Initial Hilcorp Alaska LLC NS -31 FROM: Guy Cook NORTHSTAR UNIT NS -31 Petroleum Inspector os78 'Tubing Src: Inspector 4859 Reviewed B P.I. Suprv`— NON-CONFIDENTIAL Comm Well Name NORTHSTAR UNIT NS -31 API Well Number 50-029-23009-00-00 Inspector Name: Guy Cook Permit Number: 201-060-0 Inspection Date: 8/10/2019 " Insp Num: mitGDC190810122702 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min NS -3I Type Inj G "TVD os78 'Tubing 4876 4859 4866 _� 4866 "rte JWell PTD j 2010600 - Type Test SPT Test psi 2644 - IA sss 2924 - 2911 - 2917 - — BBL Pumped: 4 IBBL Returned: 3.7 OA 69 275 - 270 " 272 ' Interval 4YRTST ' P/F p _�__-_._ l Notes: A triplex pump and bleed trailer were used for testing, along with calibrated gauges. / Monday, August 12, 2019 Page I of 1 • F w\�o �j/j�s THE STATE Alaska Oil and Gas �� �fl 1 1 1 J��1 1 C 2nEeTs v t e i11 Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue DSIP'P- Anchorage, Alaska 99501-3572 ALA AUG ntt Main: 907.279.1433 Fax: 907.276.7542 cawH*V4 Mark Sauve Petroleum Engineer BP Exploration (Alaska), Inc. aDi- P.O. Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field,Northstar Oil Pool,NSTR NS31 Sundry Number: 314-013 Dear Mr. Sauve: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount '\/ _" Commissioner DATED this / day of January, 2014. Encl. .J114* )mom £•'a�--. e:<' ti fms UckA' R % v I STATE OF ALASKA 1 A N 0 7 4: i 1 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: Water Wash ❑� ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Development ❑ Exploratory ❑ 201-060-0 • 3.Address: Stratigraphic ❑ Service Q • 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23009-00-00. 1 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 458A NSTR NS31 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312799 NORTHSTAR, NORTHSTAR OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11440 ' 11279 , 11356 11195 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 158 20"169#X-56 41-199 41 -199 Surface 3192 13-3/8"68#L-80 45-3237 45-3233.63 5020 2260 Intermediate None None None None None None Production 10884 9-5/8"53.5#L-80 l 43-10927 43-10772.19 7930 6620 Liner 658 7"29#13CR80 10781-11439 10628.66-11277.52 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths 7"HES HRQ SSV 2005',2001.71' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑., • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1/20/14 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ 0 ' WAG ❑ Abandoned ❑ Commission Representative: GSTOR El SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Email Mark.SauveQBP.com Printed Name Mark Sauve / Title PE Signature / Phone Date 564-4660 1/7/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 51 14 -UI 3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS— MAY I 0 2014 Spacing Exception Required? Yes ❑ No © Subsequent Form Required: V 0 _4 D zf APPROVED BY Approved by:,` / COMMISSIONER THE COMMISSION Date: I ? //4 Lr 6O t 1 � D ^",L l� Form 10-403 Revised 1/2010 Approvla■rslfc$i rr lraioA months from the date of approval. / Submit in Duplicate b VVV ffffff ��`��` �/5.- ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.1,DBR,LHD 11/05/73) General Information Well Name: NS31 Well Type: Natural Flow Producer Activity Description: Solvent Well Activity Classification: Conventional 4 Field/Reservoir: Northstar _ Cost Code/AFE: ANSINJEC WETS Job Type: Inj WW-Water Wash 12 Month Avg IOR,bopd: 30 AWGRS Job Scope: PROFILE MODIFICATION _ Estimated Cost, $M: Sundry Form 10--403 Reqd? Yes Sundry Form 10-404 Required? Yes Other regulatory requirements? No Base Management Engr: Mark Sauve Contact numbers: 564-4660(w), 748-2865(m), 336-6128(h) _ Well Intervention Engr: Contact numbers: Lead BM Engineer: Mark Sauve Contact numbers. 564-4660(w), 746-2865(m), 336-6128(h) Date Created: 1/6/2014 Revisions(date,who,what changed): Current Well Status Information Current Status: Operable Recent Well Test or Injection Rate and Pressure: 1/2/14. 48.8 MMSCFD®4917 psi WHP. Recent H2S (date,ppm) 8/18/13 0 If inoperable or under evaluation, why? _ Datum depth,ft TVDss,MD 11,100 TVDSS Maximum Deviation(angle and depth) 42 10,324 Reservoir pressure,psig 5,200 Minimum ID(depth) 4.892'in 7'x 5.5'XO©10,640'MD Reservoir temperature,F 250 Last downhole operation(date,operation) Water wash stimulation pumped on 4/17/13. -- Shut in wellhead pressure 4,100 Most recent TD tag, (date,depth,toolstring OD) Tagged 11,298'ELMD w 2.875"dummy gun on 6/3/05 Known mechanical integrity problems(specifics) Comments,well history, NS31 is a relatively trouble-free gas injection well in the mid-field area of the Northstar reservoir. NS31 is the#3 gas injection well(by rate)at Northstar and V background information,etc: has responded favorably to water washes in the past. Well Intervention Details Suspected Well Problem: Declining well injectivity Specific Intervention or Well Objectives 1 Stimulate perfs and improve gas injectivity. 2 3 Key risks,critical issues: Mitigation plan: 1 2 3 Summary Step# Service Line Activity 1 F Pump fresh water/diesel/xylene wash as per program 2 Ops Allow water to soak 24 hours before putting well back on injection. _ 3 Detailed work scope(If no recommended practice or standard procedure exists for the intervention type, a well specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) Expected Production Rates: BOPD MMSCFD BWPD FTP(psi): Choke setting: Post job POP instructions: POP well with gas lift as soon as possible post job. Attachments- include in separate excel worksheets Required attachments: Current wellbore schematic As needed depending on type of work: Perforating form,logging form,well test chart, annotated mini log, annotated log section, tubing/casing tallies,wellhead info,etc Approvals Base Mgmt Approval: Date: Wells Approval: Date: TREE• ABS.V r&9SI SAILFTY 1077 66: WELL RECILMWES A WV. AELL 04.A D• A BB. GI 1 3.5/6" TIBOV4A_6 SKS CSIlEIOEL A CTUA TOR- BA NS31 PCB EL - SE E - 4G8' 03 15 4 KCP 55' Hr.PROSSSV,R PIPE3•56791 .An gm. 25'Ct,888E' 41 , Da turr,6.0 10707' trr T, i- 10503 SS 11 3.3.6'CSG,8841 _80 BK. 1.1- .2 415'H 323T 105113' Hr arts a ar,o &vs-I IInim ID 4-825"ca 10688' SELF ALIGNING MULE SHOE 10604. HINCR 11501'X 7'S.3 FKR,ED-6 "A • 1--1 10626' Hr ans ap,ID,. 5.I 10640' Hr cras 1+4 kr, 515' I WW1H7"X 5-1/2"XD,D•4.892-I 7"1BG. T-95 VASA TOP NC 10632' 93131 41.II CSC ID 10602' H 12-sTh.30,.,mu_vz- Lr 0•4 D25' I TBG STL/3 '• •06' ir--1 107CA' H7-o-ns a kr,ID-SCOTI 10730' 1-113.5011"X T BK R 9.3 *6.00' I 1,--1 107 55' Hr ails a 14,,• ger I 107 er Hr ons Ppi s.Tr 1 107 ei H5x7'SKR L 141 TOP PWR I IMP OF 7' H 10781' 1 10765. Hr Wt.Ea 0.6 18e j S. 53 50 L-1,10 BTG loocir 107.5. 119.5.43'X r BK R OCR MGR.0.7 I 0 30 3 WI D•8.5 36' FERFORA 110N SUMMARY RW LOG. GRAN'05/2210 1 OLIN LOG GA10001T) ANGLE AT TOP 1:631F- 16d11075 Rota%far to Preclucaon DB for he trxast pert data 3 TIE SW INT13:1VAL G"Sqz I.U2 6 11075 111w 0 06.0805 * 4V2 5 11150 11 170 0 1119.01 4.1/2' 5 11144 11304 0 07/14001 P13 TO 11356 1S2').;trab 17-L.,.2...SICK 0371 bpi, .8 IM H 11439 DATE Fei BY 004.1149475 DATE REY BY 001ALIENTS NORTNSTA R 04.01 AJ VI TIAL CPL ET1 ON af..0 5 SAP 1/38V FCRA61 T PNEu. P631 112116,166 LV NINO amain-PtPa3 1080D 09/10,01 EW TVD OD3T16 mama ATFE)JeCRAWBIG corrEc-ncwis kaPb 50-02923(49.00 1 1/20.01 EF ADPEFFS 02/17/1 1 16113k0A3 A0120 SSSV SAFETY NOTE SEC 11.113N R13E,1316 F&&649'FEL 03106,05 4AFT11.1.. F-6.4&DEEM 06,06X:15 F11.111011.)C_PERFS BP Eqpt oration Mesa a) • 0 Minilog for Well Tec ®9 Project.NORTH STAR NS31 Ater, LAURAJ.LARSON Scale 1:600 Date 6125/2012 Injector Well: NS31 V\'/I:500292300900 Devation:56 X:660684.02 SPUD date:2001-04-2600:00:00Count,:USA Short name:NS31 Elevation datum:KB 0:6031825.03 Completion date:2001-07-03 00:00:00 Fekl:NORTHSTAR Lnng names'NORTHSTAR NO 31 Total depth:11440 Longitude:-148.693335 Status: State-Alaska Coordinate system:N1D27 AFT Latitude:70.491566 Operator:BPXA _onvan..BPXA Dm -- HSTtPYftm Neutron Porosity GR TVDSS MD .. 1KA u ^ PE (FEET( (h) PE Notes RES MED DEN a l wmP 010 Hal o 1:600 1:600 uc na P ���D ... ' aR�r .,,,, ... A'¢��.IRu ,.. SWT PHIT GR Sa RES DEP A MOSS FOli O HC?t# 50150 n z __. ',o4,11.s",.. Scat i Iiiiaah0UP t1f1i rvW JrM cwNCII io oci vOfil r 10700 O/W/C +10950- . } C- 10750-,r ....- 1 2-11000- - /, 10800.4 , Luigi . _:.‘. 1 1.;.7 _ 1 5 . `gym `11050- 4. 10850.5 S P Of _ TZE 11100 j ,---, ) 10900 'Ar C P.", APF � TZD I ( X11150- �� C y S PERF - S( 10950 , _ 2-1 P/ 11200- PER; PD • 11000—. I• • P 'OPP 1 .• • • J 11050-, VLSI PPP FP► Eli e. — 11300 - t j tlloo J __, C"`, . +11350 -- r f 1150` J t TZA1 r 5 J11100- — �-�v 7 TKVK -11200-; I s' . I — -11450- .11450- i mil I , I ma o 7-08 ry o �n � � 1 t � 1111 t.-,2° .` 2 $$sLI2P iiillri28 S000ago ee reoo i ~= IIIII 1 Wi I' — — — — mil _ z•V_P -881C°« . mi Hyo d ? - - - — 1 1 1 1 1 8`o m E 8i8 i11,AN9 8 i �i io E ' - � � N I I I 1 I_ _ - - - va ooa a aoo i I I I I 88888888888$ i m 111118 8m88 ! { o: w — — — — — i i i i i 888888888888 t it r2a 11111 oa Vm$ 1silgoxs'i E11. - - — — — I I I I I s 8 �8 �8m8 m LLE y d ;: Fi Z LLiOICN E r =a e m v 1 1 1 1 I m ai F 8rn88828888$8 N a is= • - v) — - __ __ _ a 1 1 1 1 1 m F CD I m11111 7, °8 88883e8$ O d 2. = — - — — — E H i l l 0 11 d a - m _ _ - 1 1 1 1 1 1 v Z g g g C 9g�g�88888R88 2 E H 1- 4.'. 1 1 1 1 1 ^ nRe� n n a' _ 11 a i �y — — — _ 0 mil - . = , . 1 1 1 1 1 a�EF§§§§§§E6nE 81 1 1 1 1 _- - _ - " -S. B. 1 1 1 1 1 i ig 1- - , - - - -1 1 1$1 I E s 1 1 — _ 5 li s 5 8 5 2I I 121 I - - u' E LL f w a gi;g: :.: : rc ¢ rc — — — — — 2.121 121 I Ia — — __ — — =_181 1X1 1 1 I g w E i.i _ - a m m g H 2 o 1.1 I1! d III 0 111 22;2;2;¢; -IrIM1..I ,10 L=',, 2Ei a xo a I- - $ - _= 3 -13 4 ,n a 8 8 R R 8 1'2 3 - 'FT 1 ;? o _ 5 2 E a S a cl _ g g x I g' = LL Q 2- i ! i ! r m ti a f <_ o E 6 i ilF 8 E a z a 3 i N 8 8 $ a m 0 la LL S a `o 2 8 8 8 8 8 a a i t ❑ Subsea(Wet Tree-Semi Submersible, Intervention Vessel) or Offshore Under-balanced ❑ Well rate ?15 mboed (or Operations(Snubbing) 90 mmscfd") or ❑ Multiple challenges, associated with high uncertainty (low predictability) and low Incremental added / manageability relating to a complex combination of well integrity, reservoir / wellbore restored production 5 conditions,production chemistry I flow assurance challenges. mboed(30 mmscfd') ❑ Technology/Technique new to Industry. ❑ Activity costs as per Regional VP Resource ❑ Well Activity performed on a Tier 1 or Tier 2 well, defined in GWO Wells Classification Delegation of Authority (UP 4.1-003) (DOAI Conventional 2 Complexity Criteria Conventional 2 Production/ Re4onal DoA Criteria ❑ Single or multiple element integrity test failures with identified moderate potential to ❑ Well rate 3 mboed and t'= impact or be impacted by the Well Activity; e.g. acid treatment/flowback in a well with 15 mboed (or 18 and 90 corroded tubing_ mmscfd') or Incremental ❑ Highly dynamic or poorly understood reservoir or wellbore conditions or complex added/restored production production chemistry challenges which may involve additional (beyond local norm) ='-1 mboed and -5 mboed measures to effectively manage the impact on the planned Well Activity. (6 and 30 mmscfd")-'" ❑ Challenging wellbore trajectory which may involve additional (beyond local norm) ❑ Activity costs as per measures to effectively manage the impact on the planned well intervention. Regional Base Z1Offshore Platform Rig (Dry Tree), Offshore Jack-up Rig (Dry Tree), Offshore Hydraulic Management Manager Workover Unit(Over-balanced operational, Land Drilling Rig. Delegation of Authority ❑ Technology/Technique new to BP (DoA) Conventional 3 Complexity Criteria Conventional 3 Production/ Regional DoA Criteria ❑ Single element well integrity failure is known to exist or uncertain integrity status with ❑ Well rate - 1 m boed and potential to impact or be impacted by the planned activity e.g.production log on well with 3 mboed (or 6 and 18 no Well Activity history but report of failed tree valve. mmscfd') or Incremental ❑ Dynamic but well understood reservoir or vwellbore conditions with well understood added/restored production production chemistry issues (e.g. hydrates, scale, wax, asphaltenes). Addressed by - 0.25m boed and < I established local work measures (and proven track record) to effectively manage the mboed (1.5 and 6 impact on the planned Well Activities. mmscfd')_" • Well trajectory access issues covered by established local work measures (and proven a Activity cost; as per track record)that effectively manage the impact on the planned Well Activities. Regional Base ❑ Land operations with a Hydraulic Workover Unit(Over-balanced operations) Management Team Lead Delegation of .Authority ❑ H2S concentration in reservoir/wellbore fluids> 10 ppm, partial pressure H_S > 0.05psia (DoAl or iron sulfide scale present(unless SoP exists). ❑ Technology/Technique new to Region/Team. ❑ Hazardous Materials in use during Well Activities or generation of hazardous materials during Well Activities, including corrosive (acids and caustics), toxic, cryogenic and flammable materials,explosives and radioactive sources/materials.(unless SoP exists). • Simultaneous Operations ISIMOPS): Well Activity may impact or be impacted by other work in the immediate vicinity e g. a Well Activity conducted adjacent to a new well commissioning operation. ❑ Production Facility Impacts: Either safety and operational risk impacts to or resulting from the production facility (e.g. returned fluids, pressures, etc. are likely to cause facility mpacts,or facility shutdown,start-up,etc-are likely to impact the well activity). Conventional 4 Production! Conventional 4 Complexity Criteria Regional DoA Criteria ❑ Single element integrity -anomaly"" is known to exist and being managed within existing ❑ Well rate --"s"-.1 mboed (or 6 acceptance criteria but not expected to directly impact or be impacted by the planned mmscfd') or Incremental Well Activity; e.g. slickline gauge run on a well with annulus sustained casing pressure added/restored production anomaly. <<025mboed/12 months ❑ Static or benign reservoir or wellbore conditions with no significant production chemistry (1-5 mmscfd1."" issues which might impact the planned Well Activity. ❑ Activity costs as per ❑ Well trajectory poses no access issues that might impact the planned Well Activity. Regional PE Delegation of ❑ Non-rig(Land and Offshore),Land Service Rig/Pulling Unit(unless SoP exists). Authority(DoA). All references to gas production refer to commercial gas only "Addediresio'ed prodJcticr refers to average over following 12 months Perforation Attachment ADL0312799 Well Date Perf Code MD Top MD Base TVD Top TVD Base NS31 6/6/05 APF 11075 11090 10918 10933 NS31 6/5/05 APF 11090 11150 10933 10992 NS31 11/19/01 APF 11150 11170 10992 11012 NS31 1/2/05 _ PER 11184 11198 11025 11039 NS31 3/24/05 BPP 11198 11204 11039 11045 NS31 3/24/05 BPP 11204 11244 11045 11085 NS31 3/24/05 BPP 11244 11284 11085 11124 NS31 3/24/05 BPP 11284 11304 11124 11144 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET 01-I OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF 0 cD 00 0 0 0 LO m 1•9 UCO CO CCD CD O X co J J J H N Q O O O o 0 0 co O) N N CO N CO LO O CO N o 1'- O N N- (o N I's 0) 0 j O o 0 0 0 0 L CD CO co N Co 7 (N A- CA 0 mvaol� Low a) to _ m CA CO N coCO d) N N- CD t O A- A- O M O O a o p) N co in `4" ▪ O O N a) Q N - co N N 0) CO N C j co ON) m CA V C)) N N- CO Cr) O o M 0 0 r T r r 2 C (n a N 0 CO H T- O ch Lo o 0 Ovovvo 't 2 0 0 0ao00 J co CA to * MtiicoJl- U) Co 1- 1f) tD N N A N _ CD N co O N M F- N p) co co co (h• Lo in co to) • CD O c O O J � M Z O O rn � H W U V p W p lay, Z Z Z W O m m O Z CeD U = aclHH Packers and SSV's Attachment ADL0312799 Well Facility Type MD Top Description TVD Top NS31 SSSV 2005 7" HES HRQ SSV 2002 NS31 PACKER 10604 7" Baker S-3 Packer 10455 NS31 PACKER 10730 7" Baker S-3 Packer 10579 NS31 PACKER 10781 7" Liner Top Packer 10629 STATE OF ALASKA • 0 SKA OIL AND GAS CONSERVATION COMIPSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Water Wash • Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc • Development❑ Exploratory ❑ 201 -060 -0 • 3. Address: P.O. Box 196612 Stratigraphit❑ Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23009 -00 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0312799 NSTR NS31 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): „ To Be Submitted NORTHSTAR, NORTHSTAR OIL 11. Present Well Condition Summary: Total Depth measured 11440 feet • Plugs measured None feet RECEIVED true vertical 11278.51 feet Junk measured None feet M'1 Y 3 Effective Depth measured 11356 feet Packer measured See Attachment feet true vertical 11195.36 feet true vertical See Attachment feet G CC Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 158 20" 169# X -56 41 - 199 41 - 199 4260 2590 Surface 3192 13 -3/8" 68# L -80 45 - 3237 45 - 3233.63 5020 2260 Intermediate None None None None None None Production 10884 9 -5/8" 53.5# L -80 43 - 10927 43 - 10772.19 7930 6620 Liner 658 7" 29# 13CR80 10781 - 11439 10628.66 - 11277.52 8160 7020 Perforation depth Measured depth 11075 - 11090 feet 11090 - 11150 feet 11150 - 11170 feet 11184 - 11198 feet 11198 - 11204 feet 11204 - 11244 feet 11244 - 11284 feet 11284 - 11304 feet True Vertical depth 10917.94 - 10932.7; feet 10932.73 - 10991.9 feet 10991.9 - 11011.64 feet 11025.45 - 11039.2 feet 11039.27 - 11045.11 feet 11045.19 - 11084.6 feet 11084.68 - 11124.11 feet 11124.19 - 11143.95 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 0 g n Treatment descriptions including volumes used and final pressure: SCANNED JUL 0 8 LL 13 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service E Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPIJJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ISI I SUSP ❑ SPLUCJ 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: 313 -132 Contact Nita Summerhays Email Nita.Summer Printed Name Nita Summerhays Title Petrotechnical Data Technician Signatur „i / /L! � i /r /iii /..., ff �� � / Phone 564 -4035 Date 5/13/2013 yam- - RBDMS MAY 13 201 ,i/L � . x/29- 3 Form 10 -404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0312799 ACTIVITYDATE � SUMMARY o= • e • emp= oven rea men mprove njec iv] y '®umpe • • • s meth, 100 bbls 50/50 diesel /xylene followed by 540 bbls fresh water w /.02% F -103 4/17/2013 surfactant. Freeze protected Tbg w/ 18 bbls 60/40 meth. Final WHPs 440/140/0 FLUIDS PUMPED BBLS 100 DIESEL/XYL 23 60/40 METH 540 FRESH WATER W/F -103 SURFACTANT 663 TOTAL Casing / Tubing Attachment ADL0312799 Casing Length Size MD ND Burst Collapse CONDUCTOR 158 20" 169# X -56 41 - 199 41 - 199 4260 2590 LINER 658 7" 29# 13CR80 10781 - 11439 10628.66 - 11277.5 8160 7020 PRODUCTION 10884 9 -5/8" 53.5# L -80 43 - 10927 43 - 10772.2 7930 6620 SSV 7 7" HES HRQ SSV 2005 - 2012 2001.71 - 2008.71 SURFACE 3192 13 -3/8" 68# L -80 45 - 3237 45 - 3233.63 5020 2260 TUBING 10651 7" 32# T -95 41 - 10692 41 - 10541.4 10760 9730 • TUBING 93 7" 29# L -80 10692 - 10785 10541.4 - 10632.6 8160 7020 • • • Packers and SSV's Attachment ADL0312799 SW Name Type MD TVD Depscription NS31 PACKER 10604 10399.4 7" Baker S -3 Packer NS31 PACKER 10730 10522.63 7" Baker S -3 Packer NS31 PACKER 10781 10572.66 7" Liner Top Packer TREE = ABB -VG! 7" 6 Y NOTES: WELL REQUIRES A SSSV WELLHEAD = ABB -VGI 13 -5/8" MULTIBOWL 6. I N S31 CHROM E LNR"" ACTUATOR = BAKER KB. ELEV = 56' - BF. ELEV = 40.6' (CB 15.4') I 2005' KOP = 455' ® I I-{ 7" HRO SSSV, R NIP ID = 5.875" Max Angle = 25° @ 8669' , Datum MD = 10707' Datum TV D = 10500' SS 113 -3/8" CSG, 68 #, L -80 BTC, ID = 12.415" I—I 3237' ■ I 10583' H 7" OTIS R NIP, ID = 5.875" I Minimum ID = 4.825" @ 10688' •► SELF ALIGNING MULE SHOE g I 10604' I-1 BKR9 5/8" X7" S -3 PKR, ID= 6.08" ' I 10628' H 7" OTIS R NIP, ID = 5.875" I ' ' I 10640' H 7" OTIS RN NIP, ID = 5.75" I \ / ( 10661' H 7" X 5-1/2" XO, ID = 4.892" I 7" TBG, 32 #1, T -95 VAM TOP HC 10 0361 bpf, 6.094" ID 10692' —1 5 -1 /2" STINGER w /MULESHOE, ID = 4.825" I 17" TBG STUB I-J -10692 I I 10709' I-1 7" OTIS R NIP, ID = 5.963" I Z x _ L 10730' H 9 -5/8" X 7" BKR S -3 PKR, ID = 6.00" I I 10755' H 7" OTIS R NIP, ID = 5.963" ' I I 10767 H 7" OTIS RN NIP, ID = 5.77" I 10781' I -1 9 -5/8" X 7" BKR LNR TOP PKR, ID = ?" I I TOP OF 7" LNR H 10781' I ,1 ) (1.; 1 10785' I-1 7" WLEG, ID = 6.184" I 9 -5/8 ", 53.5# L -80 BTC-M, -1 10927' Lj 10795' I-1 9 -5/8" X 7" BKR LNR HGR, ID = ?" I .0383 bpf, ID = 8.535" lk PERFORATION SUMMARY REF LOG: GR/AIT 05/22/01 I (TIE-IN LOG: GR/CCL /USIT) ANGLE AT TOP PERF: 16 deg @ 11075' Note: Refer to Production DB for historical pert data I SIZE SPF INTERVAL (MD) Opn /Sqz DATE 4 -1/2" 6 11075 - 11150 0 06/06/05 4 -1/2" 5 11150- 11170 0 11/19/01 I 4 -1/2" 5 11184 - 11304 0 07/14/01 I PBTD I - I 11356' AWAVAW 17" LNR, 29 #, 13CR, .0371 bpf, ID = 6.184" I—I 11439' DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 06/04/01 AKG INITIAL COMPLETION 11/05/05 BJM NEW FORMAT WELL: NS31 02/15/05 LV RWO 11/27/07 WRR/PJC WELLHD /LOCATIION CORRECTIONS PERMIT No: '2010600 09/10/01 EMF ND DEPTHS 06/30/08 WRR/PJC DRAWING CORRECTIONS API No: 50- 029 - 23009 -00 11/20/01 EMF ADPERFS 02/17/11 MB /JMD ADDED SSSV SAFETY NOTE SEC 11, T13N, RI3E, 1348' FSL & 649' FEL 03/06/05 JAF /THL FISH & DEBRIS 06/06/05 RMH/PJC PERFS BP Exploration (Alaska) �w�• \\ l i % : s THE STATE Alaska Oil and Gas A LAsKA Conservation Commission _ice GOVERNOR SEAN PARNELL 333 West Seventh Avenue ALA9 * Anchorage - Main: 90 9 Fax: 907.276.7542 Mark Sauve I NHED MAR 2 �0�3 Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 d Anchorage, AK 99519 -6612 Re: Northstar Field, Northstar Oil Pool, NS31 Sundry Number: 313 -132 Dear Mr. Sauve: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this day of March, 2013. Encl. , _ e • (i). STATE OF ALASKA ?J 1� 1 IA' ALASKA OIL AND GAS CONSERVATION COMMISSION , "' `.s APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. _ Water Wash n 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 201 -060-0 . 3. Address: 6 API Number. Stratigraphic ❑ Service 0 P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 23009 -00 -00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 458A NSTR NS31 , Will planned perforations require a spacing exception? Yes El No E1 1,i A. `3 • i 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0312799 ' NORTHSTAR, NORTHSTAR OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11440 • 11279 1 11356 11195 None None Casing Length Size MD ND Burst Corpse Structural Conductor 158 20" 169# X -56 41 - 199 41 -199 Surface 3192 13 -3/8" 68# L -80 45 - 3237 45 - 3233.63 5020 2260 Intermediate None None None None None None Production 10884 9 -5/8" 53.5# L -80 43 - 10927 43 - 10772.19 7930 6620 Liner 658 7" 29# 13CR80 10781 - 11439 10628.66 - 11277.52 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths 7" HES HRQ SSV 2005, 2001.71' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ID BOP Sketch ❑ Exploratory ❑ Development ❑ Service 10 • 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended El 16. Verbal Approval: Date: WINJ ❑ GINJ 10 • WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Email j ark.Sawe0BP.corri Printed Name Mark Sauve Title PE Signature ' e 564 -4660 Date 3/12/2013 COMMISSION USE ONLY j Conditions of approval: Notify Commission so that a representative may witness Sundry Number. � 3 - 1 3 2. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ ® .. r Other: R>Er mS MAR 2 1 201 11 '' Spacing Exception Required? Yes ❑ No © Subsequent Form Required: /0- 4 t APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 3 - l 3 c 6 ._ N I AL Approved application is valid for 12 months from the date of approval. Submit in Duplicate :V VLl-^ 3/f q/ f 3 ,�'M � � Versionl.1 04/28/2010 Fullbore Pumping Design Template I Well Name NS -31 Job Scope Solvent Treatment No Records H2S (ppm /date) WBL Cat IOR 5000 Max Pumping Pressure (psi) Well Type GI AFE ANSINJEC Main Fluid Type Date 3/14/2013 IOR 140 600 Main Fluid Volume (bbls) Engineer Mark Sauve Phone 564 -4660 Methanol (60/40) Freeze Protect Type Job Objective 10 Freeze Protect Volume (bbls) If Applicable Recent Tbg Fluid Level (ft) Improve injectivity by dissolving salts and possibly asphaltenes in the • If Applicable Recent IA Fluid Level (ft) tubing and formation. Diesel / Xylene washes have been used If Applicable Recent OA Fluid Level (ft) successfully in the past on the NGI/WGI /AGI gas injectors to improve If Applicable Expected Tbg Fill Up Volume (bbls) injectivity. If Applicable Expected IA Fill Up Volume (bbls) i If Applicable Expected OA Fill Up Volume (bbls) 402 Wellbore Volume to Perfs (bbls) Fullbore Pumping Schedule 5200 Anticipated Bottom Hole Pressure (psi) Pump Volume Rate Max Select Tubing/Casing within Pressure Limits? Stage Fluid Type Into (bbls) (bpm) Pressure Size Burst/Collapse 80% Burst/Collapse Tubing Burst (psi) 7 10,760 8,608 I Pre -Flush 1 I Methanol (60/40) 1 Tbg 101 51 1 50001 Tubing Collapse (psi) 7 9,730 7,784 Casing Burst (psi) 7 9,690 7,752 Solvent I Select Fluid Type I Tbg 1 1 100 1 5 1 50001 Casing Collapse (psi) 7 7,850 6,280 I Load I Select Fluid Type Tbg 11 600 1 5 I 25001 Select Input Depth Integrity Issues? No unknown 1 Freeze Protect 1 Methanol (60/40) I Tbg 1 101 1 51 1 25001 • No Input Depth 1 Select Stage 1 1 Select Fluid Type 11 Select 1 1 1. ___1 1 1 1 No 1 Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition I Select I Production Packer within Pressure Limits? Detailed Pumping Procedure Rated Packer dp Max Anticipated dp at Packer 1 10 bbls 60/40 meoh spear 2 100 bbls 50/50 diesel /xylene I Not Necessary 1 Hold Pressure on Other Strings? 3 600 bbls of fresh water with 0.02% F -103 surfactant Tubing (psi) 4 10 bbls 60/40 meoh IA (psi) 5 RDMO. Return well to gas injection OA (psi) 6 • • Fullbore Pumping Program for Field Well Name NS -31 Job Scope Solvent Treatment Well Type GI AFE ANSINJEC Date 3/14/2013 IOR 140 Engineer Mark Sauve Phone 564 -4660 H2S No Records Jolb Objective Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel /Xylene washes have been used successfully in the past on the NGI/WGI /AGI gas injectors to improve injectivity. Fullbore Pumping Schedule Stage Fluid Type Pump Into Volume (bbls) Rate (bpm) Max Pressure 1 C Pre -Flush Methanol (60/40) 1 C Tbg 10 5 5000 2 C Solvent I Select Fluid Type [ Tbg 100 [ 5 I 5000 3 [ Load Select Fluid Type 1 L Tbg I 1 600 [ 5 2500 4 Eeeze Protect I Methanol (60/40) L Tbg I 10 5 I 2500 5 Select Stage I Select Fluid Type I Select Detailed Pumping Procedure 1 10 bbls 60/40 meoh spear 2 100 bbls 50/50 diesel /xylene 3 600 bbls of fresh water with 0.02% F -103 surfactant 4 10 bbls 60/40 meoh 5 RDMO. Return well to gas injection 6 Additional Details • If Applicable Recent Tbg Fluid Level (ft) Integrity Issues? No unknown If Applicable Recent IA Fluid Level (ft) No Input Depth If Applicable Recent OA Fluid Level (ft) • • Freeze Protection - see PE manual for additional information Freeze Protect to 2500' TVD in GPB. Use 60/40 Meth Water for Injectors Use 5 bbl 60/40 Meth Water spear followed by dead crude for Producers Pipe Data (L -80) dimensions mech ' inner capacity liter cap i ', e� ,' rs 5y1 " A '� r:+: t.,, r Rm%;' s.. ,,� a,v.;: +! - u ',oP", 4;^rr .� 4 4„,,,s,r ✓ r ,,; '?'° ,�.;.:n J 2.375 4.60 2.38 2.00 1.90 11780.00 11200.00 _ 0.00387 258.6 0.00548 182.5 2.875 6.50 2.88 2.44 2.35 11160.00 10570.00 0.00579 172.8 0.00803 124.5 3.188 6.40 3.19 2.81 2.68 11111.00 1111100 0.00769 130.1 0.00987 101.3 3.500 9.30 3.50 2.99 2.87 10530.00 10160.00 0.00870 115.0 0.01190 84.0 4.500 12.60 4 50 3.96 3.83 7500.00 8430.00 0.01522 65.7 0.01967 50 8 5.000 18.00 5.00 4.28 4.15 10490.00 9910.00 0.01776 56.3 0.02429 41.2 5.500 17.00 5.50 4.89 4.77 6280 00 7740 00 0.02325 43.0 0.02939 34.0 7.000 26.00 7.00 6.28 6.15 5410.00 7240.00 0.03826 26.1 0.04760 21.0 7.000 29 00 7 00 6.18 6.06 7020 00 8160.00 0.03715 26.9 0.04760 21.0 7.625 29.70 7.63 6.88 6.75 4790.00 6890.00 0.04592 21.8 0.05648 17.7 9.625 _ 47.00 9 63 8 68 8.53 4760.00 6870.00 0 07321 13.7 0.08999 11.1 13.375 72.00 13.38 12.35 12.19 2670.00 5380.00 _ 0.14809 6.8 0.17378 5.8 custom 6.000 4.000 0.01561 64.1 0.03497 28.6 Bursts OD GRADE WT Burst 3 1/2" 80 9.3# 10160 4 1/2" 80 12.6# 7500 51/2" 80 15.5# 7000 80 17# 7740 7" 80 26# 7240 80 29# 8160 95 29# 9690 110 29# 11220 7 5/8" 80 29.7# 6890 80 33.7# 7900 95 29.7# 8180 9 5/8" 55 36# 3520 55 40# 3950 80 40# 5750 80 43.5# 6330 80 47# 6870 80 53.5# 7930 95 47# 8150 10 3/4" 55 45.5# 3580 80 45.5# 5190 80 55.5# 6450 113/4" 95 60# 6920 13 3/8" 55 54.5# 2730 55 61# 3090 55 68# 3450 80 68# 5020 80 72# 5380 95 72# 6390 16" 80 84# 4330 18 5/8" 55 96.5# 2510 55 109.3# 2910 20" 40 94# 1530 55 133# _ 3060 Brine Design Notes Revised: 5/1/00 NaCI KCI CaCI NaBr Design Notes: 8.5 29 8.4 31 8.5 30 8.5 30 8.6 27 8.5 30 9.0 22 9.0 25 Design for -50 degrees from surface to 100', 10 degrees through permafrost (approx. 2500'). 8.7 26 8.7 27 9.5 10 9.5 20 Be careful using McOH /H2H for freeze cap - McOH may mix with brine and dilute 8.8 24 8.9 23 10.0 -9 10.0 14 Don't use Ca based fluids that may come in contact with the formation. 8.9 22 9.1 19 10.5 -36 10.5 6 Be careful using CaCI in IA - may dump on formation 9.0 19 9.3 15 10.7 -51 11.0 -2 Corrosion Inhibitor: mix 25 gal of NEEC EC1124 per 100 bbls brine 9.1 17 9.5 15 10.8 -57 11.5 -11 Note: Inhibitor has a 1 day half -life 9.2 14 9.6 33 10.9 -35 11.7 -16 Be careful allowing very cold diesel to contact KCI - could form a slush 9.3 11 11.0 -19 11.8 -19 • 9.4 9 11.5 36 11.9 -10 9.5 6 12.0 6 9.6 3 12.5 50 9.7 -1 12.7 63 9.8 -5 9.9 5 10.0 25 Crystallization Temperatures for Clear Brines 40 -- KCI / CaCI 20 ""IIIIIIIM. * NaCI / AEI -44 • _ � A., / AM 411 ■ ■ ■ NaCI a � o ANt ` - . CaCI \A■ / -a- -KCI -60 L - NaBr 8 .5 9 .5 Density, PPG 10.5 11.5 12.5 • • Perforation Attachment ADL0312799 Well Date Perf Code MD Top MD Base TVD Top TVD Base NS31 6/6/05 APF 11075 11090 10918 10933 NS31 6/5/05 APF 11090 11150 10933 10992 NS31 11/19/01 APF 11150 11170 10992 11012 NS31 1/2/05 PER 11184 11198 11025 11039 - NS31 3/24/05 BPP 11198 11204 11039 11045 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0312799 Well Facility Type MD Top Description TVD Top NS31 PACKER 10604 7" Baker S -3 Packer 10455 NS31 PACKER 10730 7" Baker S -3 Packer 10579 NS31 PACKER 10781 7" Liner Top Packer 10629 ' TREE = ABB -VGI7" 6. YNOTES: WELL REQUIRES SSSV. WELLHEAD = ABB-VGI 13-5/8" MULTIBOWL 6. CHR OMEL N R"** N ' ACTUATOR = BAKER 31 KB. ELEV = 56 BF. ELEV = 40.6' (CB 15.4') KOP = 455' I I 2005' 117" HRQ SSSV, R NIP ID = 5.875" Max Angle = 25° @ 8669' a, I Datum MD = 10707' Datum TVD = 10500' SS 113 -3/8" CSG, 68 #, L -80 BTC, ID = 12.415" H 3237' 1. 10583' H 7" OTIS R NIP, ID = 5.875" I Minimum ID = 4.825" @ 10688' SELF ALIGNING MULE SHOE 10604' I-1 BKR 9 -5/8" X 7" S -3 PKR, ID= 6.08" I I I 10628' H 7" OTIS R NIP, ID = 5.875" I I I 10640' 1-17" OTIS RN NIP, ID = 5.75" I / I 10661' 1-17" X 5-1/2" XO, ID = 4.892" 7" TBG, 32 #/, T -95 VAM TOP HC — 10692' 0361 bpf, 6.094" ID 17" TBG 10692' 1 15h/2" STINGER w /MULESHOE, ID = 4.825" I I TUB ---1 -10692 I I I 10709' 1-17" OTIS R NIP, ID = 5.963" x I 10730' H 9 -5/8" X 7" BKR S -3 PKR, ID = 6.00" I a I 10755' 1 OTIS R NIP, ID = 5.963" I ' I 10767' H7" OTIS RN NIP, ID = 5.77" 10781' H9 -5/8" X 7" BKR LNR TOP PKR, ID = ?" I 'TOP OF 7" LNR I—I 10781' A ( 11 10785' (-I 7" WLEG, ID = 6,184" I 9 -5/8 ", 53.5# L -80 BTC-M, 10927' 10795' 1-19-5/8" X 7" BKR LNR HGR, ID = ?" .0383 bpf, ID = 8.535" I♦ PERFORATION SUMMARY REF LOG: GR/AIT 05/22/01 I (TIE-IN LOG: GR/CCL /USIT) ANGLE AT TOP PERF: 16 deg @ 11075' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL (MD) Opn /Sqz DATE 4 -1/2" 6 11075 - 11150 0 06/06/05 4-1/2" 5 11150 - 11170 0 11/19/01 I 4 -1/2" 5 11184- 11304 0 07/14/01 IPBTDIH 11356' :414.1A.):C.X.: I7" LNR, 29 #, 13CR, .0371 bpf, ID= 6.184" I-1 11439' •WA• ������ • DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 06/04/01 AKG INITIAL COMPLETION 11/05/05 BJM NEW FORMAT WELL: NS31 02/15/05 LV RWO 11/27/07 WRR/PJC WELLHD /LOCATIION CORRECTIONS PERMIT No: 2010600 09/10/01 EMF TVD DEPTHS 06/30/08 WRR/PJC DRAWING CORRECTIONS AR No: 50- 029 - 23009 -00 11/20/01 EMF ADPERFS 02/17/11 MB /JMD ADDED SSSV SAFETY NOTE SEC 11, T13N, R13E, 1348' FSL & 649' FEL 03/06/05 JAF /THL FISH & DEBRIS 06/06/05 RMH /PJC PERFS BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim R `P DATE: Tuesday, April 03, 2012 P.I. Supervisor �� ����� Z ' SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NS -31 FROM: Jeff Jones NORTHSTAR UNIT NS -31 Petroleum Inspector Src: Inspector Reviewed By P.I. Supry NON - CONFIDENTIAL Comm Well Name NORTHSTAR UNIT NS - 31 API Well Number 50 029 - 23009 - 00 - 00 Inspector Name: JeffJones Permit Number: 201 - 060 - Inspection Date: 3/23/2012 Insp Num: mitJJ120402122737 Rel Insp Num: I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well] NS -31 ' Type Inj G ' TVD 10455 • IA 435 3000 , 2996 2996 ' PTD 2010600 ' Type Test SPT Test psi 2613 OA 126 354 - 350 348 - Interval 4 YRTST I P /Fi P - Tubing 4786 4788 - 4787 4787 - 1 Notes: 4 BBLS diesel pumped. I well inspected, no exceptions noted. - I affikiNEDJUN 1 2 2012 Tuesday, April 03, 2012 Page 1 of I MEMORANDUM To: Jim Regg ~~~ G (Z (phi Y.1. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commis DATE: Tuesday, April Ol, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC NS-31 NOR1'HSTAR LJN[T NS-3 t Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Supr ~ ~ ~--. Comm Well Name: NORTHSTAR UNIT NS-31 API Well Number: so-029-23009-00-00 Inspector Name: Bob Noble Insp Num: mitRCN0 8032 50742 1 5 Permit Number: 201-060-0 / Inspection Date: 3/21/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Ns-31 Type Inj. TVD IA Aso 296o z96o 1 z96o -- - ---- -r -- z96o __ ---- ----- 2010600 SPT 10455 I 180 360 350 350 P.T. TypeTest Test psi /~ OA Interval aYRTST p~F P ~ -Tubing ~ 4szo _ ~ aszo asoo ~ _ asoo_ 1 Notes: ~Ecc~J APR ~ 4 200$ Tuesday, April Ol, 2008 Page 1 of 1 · ,. SARAH PALIN, GOVERNOR A'f/A~1iA OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Carolyn Kirchner ACT East PE BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 5GANNED JAN 1 7 2007 Re: Northstar Field, Northstar Oil Pool, Well Name: NS31 Sundry Number: 307-007 Dear Ms. Kirchner: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this lVãay of January, 2007 Encl. Dö í- Ó~ö .~ RECE\V\::u J(YV~ a STATE OF ALASKA ./-/~//7 . " A~ OIL AND GAS CONSERVATION COMMI N t JAN 0 4 2007 APPLICATION FOR SUNDRY APPROVAL jd-\(\).. C s CQmmission 20 AAC 25.280 ka Oil & Gas on. Operational shutdown Waiver nc ther J Plug Perforations 0 Stimulate 0 Time Extension 0 Acid Wash Perforate New Pool 0 Re-enter Suspended Well 0 4. Current Well Class: 5. Permit to Drill Number: Development 0 Exploratory 0 201-0600 ./ Stratigraphic 0 1. Type 01 Request: Suspend Repair well 0 Pull Tubing 0 Abandon Alter casing 0 Change approved program 0 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. lox 196612 Anchorage, AK 99519-6612 7. KB Elevation (It): 6. API Number: Service ø 50-029-23009-00-00 I 56 KBj 9. Well Name and Number: NS31Ý Property Designation: 10. Field/Pools(s): ADLO-312799! Northstar Field Field / Northstar Oil Pool Pool ,/ PRESENT WELL CONDITION SUMMARY 11. Total Depth MD (It): 11440 Casing Surface Production Liner Total Depth TVD (It): Effective Depth MD (It): Effective Depth TVD (It): Plugs (measured): Junk (measured): 11278.51 11356 11139.4 11198 None Length Size TVD Burst Collapse 3192 13-3/8" 68# L-80 45 3237 45 3234 4930 2270 10884 9-5/8" 53.5# L-80 43 1092743 10772 7930 6620 658 7" 29# 13Cr80 10781 11439 10628.66 11278 8160 7020 Perforation Depth MD (It): 11075' - 11304' Perforation Depth TVD (It): 10918' -11144' Tubing Size: 7"29# 7" 32# Tubing Grade: L-80 T-95 Tubing MD (It): 44 - 10785 41 - 10692 7" MCX SSV 7" HES HRQ SSV 7" Baker S-3 Packer 7" Baker SABL-3 Packer 12. Attachments: Descriptive Summaryof Proposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date lor Packers and SSSV MD (It): 2005 2037 10604 10730 13. Well Class alter proposed work: Exploratory 0 Developm ent 0 Packers and SSSV Type: Service ø Commencing Operations: 16. Verbal Approval: Commission Representative: 1/17/2007 Date: 15. Well Status alter proposed work: Oil 0 Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ ø WINJ 0 WDSPL 0 Prepò"t; u uy I.:>ary Preble 5Ö4-4!i44 17. I hereby certily that the loregoing is true and correct to the best 01 my knowledge. Printed Name Carolyn Kirchner Title Signature Phone 564-4862 COMMISSION USE ONLY Conditions 01 approval: Notily Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Other: Subsequent Form Required: 4\:),-\ NER Approved by: Contact Carolyn Kirchner ACT East PE Date 1/3/2007 Sundry Number: 307- 007 Location Clearance 0 BFL (,. J M,;. APPROVED BY THE COMMISSION Date: /·/2 .. 11" Form 10-403 Revised 11/2004 OR'Glr~AL Submit in Duplicate No portion of the belO!Ork should be performed w/out fl.taking time to ensure No Accidents, No harm to People, and No damage to the Environment To: Clark Olsen/Jerry Bixby - Well Operations Supervisor December 15, 2006 From: Bob Younger & Carolyn Kirchner - Northstar Production Engineer Subject: NS31 Acid/Water Wash AFE NSFLDWL31 Est. Cost: $ÆLM lOR: Est 100 SOPD Please perform an acid/xylene treatment with 12% DAD acid on NS31: Type lOR PR N DSWL AFE Job Description Priority Comments/Other 0 100 NS31 NSFLDWL31 Pump Acid and Water Current Status: Max Inclination: Max Dog Leg: Minimum 10: Last TO tag: Injector 24.8° at 8,669' md; 9.5° at Perfs 2.6 deg/100' at 8,385' md 4.825" @ 10,688' md, 5.5" 17# stinger w. muleshoe 06/05/05: Tagged TO @ 11,150' WLM 03/23/05: Drift to TO @ 11,295' SLM Last Downhole Op: 06/05/05: Shot perfs 11,075' - 11,150', 6 SPF. Bounced down hole from tension spikes caused by dry chrome tubing. Latest H2S value: None anticipated Recent signs of decreasing injectivity have prompted the need for an acid treatment to help clear any scale that has built up in NS31. Due to success in past year(s) with acid treatments, a 12% DAD Acid wash (includes 20% xylene) is recommended. Procedure 1. Mobilize pumps, tanks and acid transport to Northstar. 2. Order out volume of seawater and methanol. 3. RU pumping equipment. 4. Hold PJSM. 5. Preheat seawater 80°F. 6. PT Dowell surface lines to 5000 psi. 7. Pump the following treatment at maximum rate or 3500 psi max pressure. a) 77 bbls 12% DAD Acid b) 900 bbls Seawater (To displace acid away from wellbore) c) 5 bbls Methanol (spacer between water and gas) C:\Documents and Settings\preblegb\Local Settings\Temporary Internet Files\OLKBC\NS31 Acidizing Procedure 12-15-06.doc No portion of the belO!Ork should be performed w/out Ii_taking time to ensure No Accidents, No harm to People, and No damage to the Environment 8. Slowly open injection choke. Step the injection pressure from 4000 psi to full injection pressure over a 4 hour period. 9. RD Schlumberger. Fluid descriptions: 80:20 DAD Acid (12% HCL) to contain: 0.6% A261 Corrosion Inhibitor 4 ppt A 179 Corrosion Inhibitor 8 ppt A 153 Corrosion Inhibitor 0.5% W54 Non-Emulsifier 0.2% F103 Surfactant 20 ppt L58 Iron Control 0.5% W60 Anti-sludge 20% Xylene Note: Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. Note: Please have Schlumberger send a digital copy of the post job report (including a digital, ASCII or EXCEL, copy of the pumping rates and pressures) to RobertYounger@bp.com. Procedure Contacts: Bob Younger WK: 564-5392 HM: 677-2599 Cell: 830-4920 C:\Documents and Settings\preblegb\Local Settings\Temporary Internet Files\OLKBC\NS31 Acidizing Procedure 12-15-06.doc . . Date: 08-22-2006 Transmittal Number:92819 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. c2 b) - ) ~ ð SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type NS08 03-28-2006 SCH PERF RECORD NS08 06-01-2006 SCH PERF RECORD NS14A 01-20-2006 SCH DEPTH CONTROL NS16 05-05-2006 SCH PRODUCTION PROFILE PERF RECORD WITH NS31 06-05-2005 SCH GAMMA RAY NS30 04-15-2006 SCH JEWELRY LOG NS30 04-02-2006 SCH JEWELRY LOG PERF RECORD WITH NS30 04-14-2006 SCH GAMMA RAY - NS19 05-15-2006 SCH PERF RECORD oU Plea e ign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center ') '~ Attn: Cheryl Ploegstra Howard Okland Tim Ryherd Ignacio Herrera Doug Chromanski SCANNED ¡~UG ~3 1 2005 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 . . Date: 03-15-2006 Transmittal Number:92763 2; {{jOE BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091 ~() 1- ()~\:; SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type VISION SERVICE LWD MD NS05PB1 02-25-2005 SCH 1 200 11991 COMPOSITE VISION SERVICE LWD TVD NS05PB1 02-25-2005 SCH 1 200 11991 COMPOSITE NS14 01-07-2006 SCH 1 9900 10300 BRIDGE PLUG SET RECORD NS24 03-26-2005 SCH 1 12150 12478 MEM PSP PPROF NS10 12-26-2005 SCH 1 4800 8025 CHEMICAL CUTTER RECORD NS14 12-22-2005 SCH 1 11500 11867 CHEMICAL CUTTER RECORD NS08 10-26-2005 SCH 1 11130 11915 CHEMICAL CUTTER RECORD NS19 09-26-2005 SCH 1 13700 13990 PERFORATION RECORD NS27 06-06-2005 SCH 1 10950 11300 PERFORATION RECORD NS31 06-05-2005 SCH 1 10950 11320 PERFORATION RECORD NS24 09-22-2005 SCH 1 11800 12470 PERFORATION RECORD NS25 10-03-2005 SCH 1 18750 19200 PERFORATION RECORD NS21 07 -31-2005 SCH 1 22050 22225 PERFORATION RECORD NS08 12-16-2005 SCH 1 9500 11244 PERFORATION RECORD NS05 09-19-2005 SCH 1 13210 14002 PERFORATION RECORD NS06 09-17 -2005 SCH 1 13040 13825 PERFORATION RECORD NS18 12-08-2005 SCH 1 16200 16834 PERFORATION RECORD NS17 07 -29-2005 SCH 1 17850 18200 PERFORATION RECORD Petro technical Data Center LR2- ] 900 E. Benson Blvd. PO Box ]96612 Anchorage, AK 99519-6612 ~/-ß~ò Fd-t.. . . BPXA WELL DATA TRANSMITTAL I I I I I Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Cheryl Ploegstra Howard Okland Tim Ryherd Doug Chromanski Ignacio Herrera Petrotechnical Data Center LR2-1 900 E. Benson B]vd. PO Box 196612 Anchorage, AK 995] 9-66] 2 Date: 03-15-2006 Transmitta] Number:92763 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc ) ) Date: 10-25-2005 Transmittal Number:92705 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If you have any questions, please contact me in the PDC at 564-4091 SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type NS21 01/15/2005 SCH 21950 22200 PERFORATING RECORD NS17 08/08/2004 SCH 17752 18255 PERFORATING RECORD NS31 02/05/2005 SCH 1 3000 10700 FREE POINT RECORD NS21 06/14/2004 SCH 22050 22242 PERFORATING RECORD STEP RATE INJECTIVITY NS32 05/15/2004 .sCH 0 8321 TEST WITH RST NS27 07/21/2004 SCH 1 0 11332 INJECTION PROFILE PERFORATION RECORD NS13 01/19/2005 SCH 11550 11858 WITH GAMMA RAY scANNEI) NO\~ (~2 2005 J/Jof[[. Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Jim Seccombe (BPXA) Attn: Cheryl Ploegstra (BPXA) Attn: Jason Smith (Murphy Exploration) Attn: Howard Okland (AOGCC) Attn: Kristin Dirks (DNR) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 19-6612 Â()I-~~ F:¿ , STATE OF ALASKA '\ ALA,- lOlL AND GAS CONSERVATION COMrv......SION REPORT OF SUNDRY WELL OPERATIONS D D D ,'(" 1'" 'i\ll'''~fT; ,) '6."ð'Õ~,¿ .'1 ~ '':j ~;;,." :.,,- Treatment descriptions including volumes used and final pressure: see attached fluid summary TIO 330/0/0 13. 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 56 KB 8. Property Designation: ADL-312799 11. Present Well Condition Summary: Total Depth measured 11440 true vertical 11278.51 Effective Depth measured 11356 true vertical 11195.36 Casing Length 3192 10884 658 Size 13-3/8" 68# L-80 9-5/8" 53.5# L-80 7" 29# 13Cr80 Surface Production Liner Perforation depth: Measured depth: 11075 - 11150 True Vertical depth: 10917.94 - 10991.9 Tubing: (size, grade, and measured depth) Packers and SS8V (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic Stimulate 0 Other CJ" · I Waiver D Time Extension D . Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory Service 201-0600 &(: 6. API Number: 50-029-23009-00-00 9. Well Name and Number: NS31 10. Field/Pool(s): Northstar Field/ Northstar Oil Pool feet Plugs (measured) None feet Junk (measured) None feet feet MD TVD Burst Collapse 45 - 3237 45 - 3233.63 4930 2270 43 - 10927 43 - 10772.19 7930 6620 10781 - 11439 10628.66 - 11277.52 8160 7020 11150 - 11170 11184 - 11304 10991.9 -11011.64 11025.45 - 11143.95 7"29# 5-1/2" 17# 7"29# L-80 L-80 L-80 44 - 10785 10661 - 10692 10692 - 10785 7" MCX SSV 7" Baker 8-3 Packer 7" Baker SABL-3 Packer 2005 10604 10730 :)[P (~ ~1, 20U5 RBDMS BFl SEP 1 6 2005 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 83550 641 o 85006 326 15. Well Class after proposed work: Exploratory r Development r 16. Well Status after proposed work: Oilr Gas r WAG r Tubing pressure 4837 4678 Service F7 WDSPL r GINJ ~ WINJ r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Sharmaine Vestai. / Signatur~ 7J~d Contact Sharmaine Vestal Form 10-404 Revised 04/2004 Sundry Number or N/A if C.O. Exempt: 305-078 Title Data Mgmt Engr Phone 564-4424 Date 9/14/2005 , '\ l ! .1\' , . ~ .~... ~,~ j '_'\ - Submit Original Only ) ) NS31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 8/8/2005 acid/water wash; initial rate 79 mmscfd @ 4737 psi. pumped 5 bbls meth spear, 73.5 bbls 12% DAD acid, 879 bbls seawater, 5 bbl meth cap returned well to tender to POI at reduced rate. FLUIDS PUMPED BBLS 73.5 12% DAD acid 10 Methanol 978 Freshwater 82 Gallons L-64 55.5 L-60 ) ') ~! - & &0 I~ fl. 'â" .11 ír Œi "1 ! I I // II l . æ: u! ,\U [I r-: ! @,rl(¡7 {Æi / i 1 j {\ 'í' .' 6 ' ,: , 11 ill\'\ \\, [ll. ,/~~ " ,I ,L \'\ ¡;.~ ,/lJ. í. I I I J "I f. "I \ ' biJ1JcQ)U'~'! \ Iii ,/ t AIfASIiA OIL AM) GAS CONSERVATION COJDDSSION /' (~n' I[ I ,I, Iliil::::! 'll : ! I 'I I r , :. 0U FRANK H. MURKOWSKI, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 SCq~NNED JUL 1 2 2005 Re: Northstar NS31 Sundry Number: 305-165 Dear Mr. Francis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. PI~ase note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on holiday or weekend. A person may not appeal a Commission decisio to Superior Court unless rehearing has been requested. DATED thislL day of July, 2005 Encl. bp ) ) .,~ ..~'.'if.l. -...~~ ~...- ~-4>.:- -:..~ ..~ F..... ·'I'~~§\" ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 5, 2005 'I' ~ I Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: .", I~ Re: Sundry Notice for NS31 to Acidize/Water Wash (Ivishak) BP Exploration Alaska, Inc. proposes to acidize and water wash the NS31 well. NS31 recently had perforations added. Last year acidizing proved to be very /"'" effective at cleaning up new perforations in injection wells and improving gas injectivity. The procedure includes the following major steps: Bullhead HCI based acid treatment and displace with water. /" Return well to gas injection . . Sincerely, ~ ~ 'oh.J t ç (l-J3 Mich el J. Fraj¡_~ J . Senior Petroleum Engineer BPXA, ACT, Northstar 1W4/t 7/71zoð)" ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION ::1\ APPLICATION FOR SUNDRY APPROVAL I": 20 AAC 25.280 1. Type of Request: D Abandon Suspend D Alter Casing D Repair Well D Change Approved Program D Pull Tubing D 2. Operator Name: 3. Address: 7. KB Elevation (ft): Operation Shutdown Plug Perforations Perforate New Pool D D D PerforateD Waiver 0 StimulateŒ] Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 201-0600 / / Other 0 4. Current Well Class: BP Exploration (Alaska), Inc. Development D Exploratory D P.O. Box 196612 Anchorage, Ak 99519-6612 6. API Number 50-029-23009-00-00 / StratigraphicD Service Œ] 9. Well Name and Numbes: NS31 / 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 8. Property Designation: ADL-312799 56.00 KB 11. Present Total Depth MD (ft): 11440 Casing SURFACE INTERMEDIATE PRODUCTION Plugs (md): Junk (md): 06/03/2005 TD Tag 11298 Burst 11223.0 11356 11141.5 Length Size MD TVD top bottom top bottom 3192 13-3/8" 68# L-80 45 3237 45.0 3233.6 10884 9-5/8" 53.5# L-80 43 10927 43.0 10772.2 658 7" 29# 13Cr80 10781 11439 10628.7 11277.5 None Collapse 4930 7930 8160 2270 6620 7020 Perforation Depth MD (ft): 11075 - 11150 11150 - 11170 11184 - 11304 Perforation Depth TVDss (ft): 10862 - 10936 10936 - 10956 10969 -11088 Tubing Size: Tubing Grade: Tubing MD (ft): 7 " 29 # L-80 41 10661 5-1/2 " 17 # L-80 10661 10692 7 " 32 # T-95 10692 10785 Packers and SSSV Type: 7" Baker $-3 Packer 7" Baker SABL-3 Packer 7" Liner Top Packer 7" MCX SSV 12. Attachments: Packers and SSSV MD (ft): 10604 10730 10781 2005 13. Well Class after proposed work: Description Summary of Proposal ŒI Detailed Operations Proç¡ram 0 BOP Sketch 0 14. Estimated Date for Commencing Operation: /' July 19, 2005 Exploratory 0 DevelopmentD 15. Well Status after proposed work: Oil D GasD Service Œ] Date: WAGD GINJ[i] ;!Ugged D Abandoned D WINJD WDSPLD Prepared by DeWayne R. Schnorr 564-5174. Michael Francis 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Conditions of approval: Other: Subsequ Contact Michael Francis ~ 'fÝ~,-Jw., j Q '- f(;./Yt/~) ~ I~ - (j' - Commission Use Only Notify Commission so that a representative may witness Title Phone Petroleum Engineer 564-4240 7/5/05 Sundry Number: \-'~o~-/(?r BOP TestD Mechanciallntegrity R8f)Ms BFLLocation Clearance D " ,JUl 1 :; 2D05 I" .- 404 . n RIG! N A I ~~~~g~~~~ION Date: ~ if SUBMIT IN~¡~!rE{) NORTHSTAR UNIT WB..L: NS31 PERMIT No: ?? API No: 50-029-23009-00 SEC T N R E BP Exploration (Alaska) DA TE REV BY COMMENTS 06/04/01 AKG INITIAL DIAGRAM 09/10/01 EMF TVD DEPTHS 11/20/01 EMF ADPERFS 02/15/05 LV ACTUAL COMPLETION 03/06/05 JA F/THL FISH & DEBRIS DA TE REV BY COMMENTS 06/06/05 RMHlPJC PERFS 7", 29#, 13Cr 7" LINER TOP @10781' MD 10629' TVD 6.184" 10 aker SABL-3 PACKER 6.00" 10 @10730' MD 10579' TVD Jet (':ut ~'Î 0(392' t,,1D w!HES M"1 068H', ~:~~ ~~ ~~ ;~' =n';~~'~:;) ir~~ ~Jj i~¡~' <~~ :ì 0 e .. B ~-!3aker S<) F)":\(,:l<er-1 0604' MD I I '.'\ . ,'I HOR SSSV 2005' MD '1" n Nippk" ,,::: 5.87S" )KB. ELEV = 56' KB-BF. ELEV = 40.6' BASE FLANGE ELEV = 15.4' ... /" ~ Q I ~ PBTO @11356' MO 11195' TVO TO @11439' I ÆRFORA TION SUMMARY REF LOG: GRlAIT (5/22/01 )Tie-In Log: (GRlCCLlUSIT) ANGLEATTOPÆRF: @ 11075 Note: Refer to Production DB for historical perf data Initial Perf-Charge: 4505 Power Jet, HVX Penetration 54", Hole: 42", Phase: 72 deg SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 6 11075 - 11150 0 06/06/05 4-1/2" 5 11150-11170 0 11/19/01 4-1/2" 5 11184-11304 0 07/14/01 ~ 95/8", 53.5#/ft L-80, BTC-M @1 0927' 7" R NIPPLE, @ 10709' & 10755': 5.963" 10 (OTIS)_ 7" RN NIPPLE, @10767' 5.77" 10 (OTIS) 7" WLEG, @10785' ~. 6.184" 10 (OTIS) - T' F~ NIPPLJ:'::, "-10583' b,S7S" 10 (OTIS) T' H NIF>F>LE, ""'10628' ::::iiI (.; 0'('/:'" 11") (")TIC',I----- ..:::::! "', . C) ,) ,,, \ \.~ ~ ..,) ¡ ___________ 7" ¡:~N NIPPLE,"'10639' (O'!"IS) /,", 32#lft, T,,~)S, VarnTopr'1(; TUBINC ID: 6J)94" Minimum ID = 4.825" @ 10688' SELF ALIGNING MULE SHOE ~ 13 3/8", 68#/ft, L-80, BTC @3237' FROM DRLG - DRAFT NS31 ) TREE: ABB-VGI 7" 6.5 ksi WELLHEAO:ABB-VGI 13-5/8" 6.5 ksi Multibowl "._..~,..., \,~II "~I 'i\~I:'" , "\\;\~ 1<:\.,",", Mé~il' ) ) GlJf~r í ULJ~ i if\L d..O (- O{¡:;O WESTPOR1 ~·(B'19tr.~mÐII!W Reservoir Fluids PF-02-067 May 2002 ~..'~ ~-!!I ~ ~ ~ ~" . .~~., Vú '---«) q¡ r./ 'h rt~ ./ (() ~ ij)., ~ 0/> ~ ~ (?~ c.(j' ~ ~~ rge ~'f ~.r. . ~ ~ SLIM TUBE STUDY NORTHSTAR N-31 SCANNED JUl 11 '2005 Work by: C. Pelletier Westport Technology Center International 6700 Portwest Drive Houston, Texas 77024 (713) 479-8400 (713) 864-9357 (Fax) www.westport1.com Prepared for: BP-Alaska W.O. #: M21204MOOO Westport Technology Center International makes no representations or warranties, either express or Implied, and specifically provides the results of this report "as Is" based on the Information provided by client. I: , WESTPORT TECHNOLOGY CENTER INTERNATIONAL DISCUSSION Slim Tube Study for BP-Alaska, Northstar N-31 During open hole logging, formation tester samples were collected from the N-31 well in the Ivishak interval at 11 ,224 ft. The samples were transferred by Oilphase personnel and shipped to Westport Technology Center in Houston. The purpose of these samples was to perform PVT analysis and slim tube studies. The results of the PVT Program were reported as Westport Report number PF-02-002. This report provides the results of the slim tube study analyses performed on the sample. The bubble point of the sample was 4714.6 PSL, which is lower than expected for the reservoir fluid. Slim Tube 1 The composition of the reservoir fluid is presented in Table 1. This table is comparable to Table 8 of PF-02-002. Table 2 lists the slim tube properties measured before the flood and the results of a SARA analysis of the stock tank oil and an analysis of the residual liquid recovered after the first slim tube flood. A reduced data table is presented in Table 3 of the report and is graphically presented in Figure 1. The slim tube run was done at a backpressure of 5175 psia and 254 of as the target and a pressure match of +/- 15 psi. This slim tube run showed a 1.2 PVI recovery of 92.80/0. The recovery at the end of the flood was 93.87°10 at 1.64 PVI. There was some vaporization of recovered liquid late in the flood. An additional 0.47 g of liquid was recovered during the toluene displacement, leaving a material balance mismatch of 4.3°10 or .93 grams or about 1 liter of gas. The material balance was run only on liquids using a formation volume factor. Table 4 provides the compositions of the gas evolved at atmospheric pressure at different pore volumes of solvent injected. The rightmost column is the solvent composition. Slim Tube 2 Table 5 presents slim tube properties measured before the flood and the results of a SARA analysis of the stock tank oil and an analysis of the residual liquid recovered after the second slim tube flood. Table 6 provides the data table for the second slim tube at the same conditions. The initial recovery from this run was 85.8°10. Going by a 90°10 cutoff for a non-miscible run the solvent gas would be immiscible at these conditions. The graphical representation of slim tube run #2 is shown in Figure 2 of the report. The evolved gas compositions verses pore volumes injected are presented in Table 7. Prepared for BP-Alaska 3/1/04 PF-02-067 Page 1 ') ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL Slim Tube 3 A number of circumstances intervened to delay the program: the existing data acquisition system died, a leak was detected in the injection pump, requested slower rates amplified sensitivities to all leaks and instabilities of the SPR system. Two slow rate tests were attempted but the results were inconclusive. The differential pressures were at or below the resolution pressure of the gauges adding to the uncertainty and inaccuracy of the measurements. Even the densitometer readings proved quite unreliable, most likely because of uneven displacement of the fluids present in the measuring tube. Consequently, it is now believed that no meaningful conclusions can be derived from both attempts to run a third slim tube test. Additional studies undertaken to better understand the slim tube performance included transverse dispersion coefficient measurements on the tube using toluene to model the oil and pentane to model the injection gas. Table 8 contains the properties of the fluids at the displacement condition. In the future, a larger diameter and consequently larger volume system should be employed. This should damp some of the backpressure regulation instabilities. Prepared for BP-Alaska 3/1/04 PF-02-067 Page 2 WESTPORT TECHNOLOGY CENTER INTERNATIONAL Slim Tube Apparatus & Operation Description The slim tube apparatus is shown in Figure 1. The system consists of the solvent delivery system; the slim tube itself and in the lower left the backpressure regulator and low-pressure sample train. The system is run either to measure minimum miscibility pressure (MMP) or Minimum Enrichment Minimum Miscibility Pressure. It uses the same solvent for each run but pressure is varied until efficient recovery occurs. Minimum Enrichment is determined (ME): at a set pressure and the composition of the solvent is varied. (A very good solvent diluted progressively with methane or flue gas.) A mercury pump drives test solvent or oil into the slime tube or through the bypass. The slim tube is a 50-foot by 0.183 in diameter stainless steel tube packed with 100/120 mesh gas beads. The permeability of the system is high compared to rocks 20 to 30 Darcies. The tube has an entrance manifold and bypass similar, to most core flood sets. Downstream of the slim tube are a series of instruments: high-pressure densitometers, the backpressure regulator, oil and gas separator and then a gasometer. The low-pressure sample train is also shown. Fluids exiting the backpressure regulator enter a separator jar on a balance the gas leaves the separator passes through sampling balloons and enters the gasometer. Figure 1: Slim Tube Apparatus 9':;:'~ l;SJJ LP~ ~~..l"i-'"._'''''-'''-''' A'- - · ~ ,""""000 . . ~ ~,I ~ ~ Gas Oil 3 f "",",,-,Y""=... -~4f\~': ~ :T _I ~ 'rlJ-'s,-! DI ¿ "---' 1 6 1 --A I .~y¡ ±~ ~~.~t~~ ---.-- ~Q",,-p.rSC;'21.[Q_,F,m\l,;:nt Prepared for BP-Alaska 3/1/04 PF-02-067 ~ J. < t~ $;--- (j) [ --< Page 3 ') ') WESTPORT TECHNOLOGY CENTER INTERNATIONAL A run starts with the tube loaded with toluene, which is displaced by dead oil, followed by live reservoir fluid. The system is shut in at the bypass, the solvent under test is loaded into a solvent cylinder and the flow path from the solvent cylinder to the backpressure regulator (BPR) is cleaned and loaded with the test solvent. The pump is set to the required rate and the pressure of the BPR is adjusted. The run is started by diverting the flowing solvent into the slim tube and sealing the bypass. During the slim tube run, a computer monitors pump rate, differential pressure, density, below the BPR cumulative liquid mass and gas volume are recorded. Separator gas samples are taken as requested by the client. At the end of the slim tube run the separator vial is changed, the gasometer is reset and instead of blowing down the slim tube, toluene is injected. The initial 30 to 50 cc of all toluene recovered is collected and distilled. The residual oil from the slim tub run is the recovered fluid diluted with toluene. The distilled fraction is analyzed to determine the toluene content, and the residual oil mass. The resultant mass of residual material is added to the material balances as the last point on the slim tube graph. Sara analysis maybe run on the residual fraction to determine, Saturates, Aromatics, Resins and Asphaltenes contents. Turnaround time between minimum miscibility runs is typically three days. The turnaround time between minimum enrichment studies is longer due the blending and analysis of each solvent batch. In addition to measuring the recovery, the phase exiting slim to can be determined by watching the high-pressure densitometer trace. During single-phase production, the densitometer trace is stable. When multiple phases are flowing, the densitometer trace reflects the variation in phase densities. This behaviors characteristic in the can be used to estimate transition zone occurrence and length. The densitometer trace can also be used to determine breakthrough. The determination of breakthrough can be confirmed through the GOR. Since the tube is loaded with toluene, permeability is checked as part of the clean up process. In preparation for a round of slim tube test, the pore volume and permeability are measured. Data Reduction and Comparison At the beginning of each slim tube run, a small volume from the end of the slim tube to through the backpressure regulator is filled with solvent gas. The response from the sensors down stream of the tube are time shifted. As fluid is displaced from the packed tube through each sensor, each of the sensor responses will be linearly time shifted from the differential pressure. The order is differential pressure (which is real time), the densitometer, and lastly the oil mass and gasometer. T he other startup effect is a slight pressure build up required to push oil from the tube. The viscosity of the oil and the absolute pressure of the test effect this portion of the flood. Prepared for BP-Alaska 3/1/04 PF-02-067 Page 4 WESTPORT TECHNOLOGY CENTER INTERNATIONAL The slim tube is run to a minimum of 1.2 pore volumes injected. A typical slim tube run is 1.5 PVI. Typically, results indicating high recovery, late breakthrough and a smooth transition from oil density to gas solvent density are associated with thermodynamic miscible systems. High recovery with multiple phase flow, and late breakthrough in the 90 to 95 percent range is indicative of multiple contact miscibility. Recovery reported at 1.2 PVI and higher than 95% may be called "Miscible" without being "thermodynamically miscible" . When comparing slime tub runs recoveries closer than 3 percent are indistinguishable from each other breakthroughs closer than 3 percent are also indistinguishable. The comparison of runs should also take into account total material balance and any recovery due to liquids from a rich solvent. Comparison of slim tube runs between different slim tube rigs is difficult; differences in geometry, packing and operating procedures will result in differences in almost all reported results. Prepared for BP-Alaska 3/1/04 PF-02-067 Page 5 ) ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL Table 1. Fluid Compositions - Northstar Slim Tube Floods Single Stage Liquid Flash Compositions Single Stage Flash GOR 2205 Scf/STB Gas SG 0.7909 STO Composition Flashed Gas Compositions 5150 PSIA 80°F 0.616074951 Cal Mw> 170.5 Cal Mw> 22.9 Cal Mw> 55.7 Gas Oil Gas Oil Gas Oil Vol (CC) 1.000 01.001 2031.06 5.173 Density (gm/CC) 0.8214 9.84E-04 9.836E-04 0.8214 Grams 1.9978 4.2488 Mole % 77.77% 22.23% API 40.620 Wt% 31.98% 68.02% Mole Wt Component Wt% Mole % Wt% Mole % r 5.46 Wt% Mole % MW (Katz Et al) Hydrogen Sulfide 0.000 0.000 Gal/Met 34.080 Nitrogen 0.000 0.000 0.017 0.014 Nitrogen 0.005 0.011 28.013 Carbon Dioxide 0.000 0.000 11.227 5.844 CO2 3.591 4.544 44.010 Methane 0.000 0.000 52.681 75.226 C1 16.849 58.487 16.043 Ethane 0.008 0.045 11.495 8.758 2.338 C2 3.682 6.819 30.070 Propane 0.196 0.756 11.341 5.892 1.620 C3 3.760 4.749 44.097 iso-Butane 0.246 0.721 2.210 0.871 0.285 iC4 0.874 0.837 58.123 n-Butane 1.012 2.967 4.435 1.748 0.551 nC4 2.106 2.018 58.123 iso-Pentane 0.981 2.317 1.197 0.380 0.139 iC5 1.050 0.810 72.150 n-Pentane 1.522 3.596 1.269 0.403 0.146 nc5 1.441 1.112 72.150 C6 3.206 6.505 0.933 0.248 0.096 C6 2.479 1.643 84.000 Benzene 0.289 0.631 0.055 0.016 0.004 Benzene 0.214 0.153 78.120 C7 5.628 9.994 0.892 0.204 0.084 C7 4.114 2.386 96.000 Toluene 0,784 1.451 0.080 0.020 0.007 Toluene 0.559 0.338 92.150 C8 7.319 11.660 0.718 0.144 0.065 C8 5.208 2.710 107 C9 6.079 8.564 0.526 0.094 0.047 C9 4.303 1.981 121 C10 5.480 6.971 0.410 0.066 0.036 C10 3.859 1.604 134 C11 4.465 5.178 0.307 0.045 0.026 C11 3.135 1.188 147 C12 4.089 4.329 0.141 0,019 0.012 C12 2.826 0.978 161 C13 4.440 4.325 0.064 0.008 0.005 C13 3.041 0.968 175 C14 4.138 3.713 C14 2.815 0.825 190 C15 3.896 3.224 100.000 100.000 C15 2.650 0.716 206 C16 3.356 2.577 C16 2.283 0.573 222 C17 3.157 2.271 Heating Values BTU/CF C17 2.148 0.505 237 C18 3.130 2.126 Grossi 1231 C18 2.129 0.472 251 C19 2.947 1.910 Net 1118 C19 2.004 0.424 263 C20 2.460 1.525 C20 1.673 0.339 275 C21 2.249 1.318 C21 1.530 0.293 291 C22 2.127 1.189 MW 22.909 C22 1 .447 0.264 305 C23 1.930 1.035 SG 0.7898 C23 1.313 0.230 318 C24 1.790 0.922 Z STP 0.9928 C24 1.218 0.205 331 C25 1.649 0.815 C25 1.121 0.181 345 C26 1.545 0.734 Calc. Critical T & P C26 1.051 0.163 359 C27 1.495 0.681 (OF) -47 C27 1.017 0.151 374 C28 1.436 0.631 (PSIA) 684 C28 0.977 0.140 388 C29 1.317 0.559 C29 0.896 0.124 402 C30 1.367 0.560 C30+ 0.930 0.125 416 C31 1.060 0.420 C31 0.721 0.093 430 C32 1.034 0.397 C32 0.703 0.088 444 C33 0.987 0.367 C33 0.671 0.082 458 C34 0.863 0.312 C34 0.587 0.069 472 C35 0.743 0.261 C35 0.505 0.058 486 C36 9.580 2.445 C36+ 6.516 0.543 668 100.00 100.00 100.00 100.00 Prepared for BP-Alaska 31112004 PF-02-067 Page 6 WESTPORT TECHNOLOGY CENTER INTERNATIONAL Table 2. Slim Tube Properties - Northstar Slim Tube Flood 1 Pore Volume Tube Length Permeability Porosity Flood Injection Rate Linear Velocity 58.37 cc 60.25 ft 17.6 Darcy 40.7 % 1.53 PV/day 92.1825 fUday 0.062 cc/min Sample Description Westport 10 Saturate % Aromatic % Polar % Asphaltene % Original Oil Analysis WTC5713.D 66.74 27.53 5.64 0.10 Residue Analysis HCJ766.d 55.63 31.95 11.06 1.36 Prepared for BP-Alaska 3/1/2004 PF-02-067 Page 7 WESTPORT TECHNOLOGY CENTER INTERNATIONAL TIme 7/5/199723:28 716119970:14 716119971:02 716119971:48 71611wJT 2:01 716119972:36 716119973:23 716119974:10 7/6/19íf74:28 716119974:56 716119975:44 716119976:31 716119977:17 716119978:05 716119978:51 716119979:38 7161199710:27 716119íf7 11:03 7/6/199711:12 716/199712:00 7/6/199712:24 716/199712:46 716/1997 13:34 716/199714:21 71611ø97 14:34 . 716/199715:07 716/199715:55 716/199716:42 716/199717:28 7/6/199718:16 71611WT 19;03_ . 716/199719:50 716/199720:36 716/199721:25 716119íf7 22:11 716/199722:59 716/199723:45 7f711997 0:32 7n/19íf7 1:10 Gas Simple Prepared for BP-Alaska 3/112004 ðr- LGluea XPVI 0.000 0.049 0.100 0.150 0.163 0.200 0.250 0.300 0.319 0.350 0.400 0.450 0.500 0.550 0.600 0.649 0.701 0.740 0.750 0.800 0.826 0.850 0.900 0.950 0.964 0.999 1.050 1.100 1.150 1.200 1.250 1.300 1.349 1.400 1.450 1.501 1.550 1.600 1.640 Table 3. Slim Tube 1 Summary· Northstar Slim Tube Flood 1 Solvent 1 1: Gas Cum Oil Oven UII VOIUI"G % I"UI,,"'U/'( mc;",u/'( (psi) (ml) (gm) Temp. (oF) RM T ("F) Auld Rho Eluted (cc) Recovery (SCF / STB) (SCF / STB) 2.0 0 0 254.8 81.1 0.393 0.0 0.0 3.0 788 1.148 254.9 81.4 0.543 1.41 6.09 2,838 3,219 3.0 1,395 2.019 254.2 81.4 0.544 2.48 10.72 2,858 2,476 Adj P _In Adj P _out AVG Press AP 5179 5183 5188 5190 5191 5190 5191 5191 5190 5188 5185 5180 5175 5174 5171 5167 5167 - 5162 5162 5117 5180 5185 5189 è;V~{n-;< 5187 5188 5178.0 5181.5 5186.5 5189.5 '\~t~:jHi'i 5188.5 5189.5 3.0 3.0 2,322 3.639 254.7 2,876 4.639 255.0 3,990 6.661 254.3 4,537 7.645 254.2 5,098 8.632 254.5 5,170 9.816 255.1 6,328 10.817 254.4 6,880 11.789 254.5 7,411 12.71 254.4 8,349 14.303 254.6 5188 5188.0 .0 5185 5185.0 .0 5181 5180.5 - 1.0 5175 5175.0 .0 5174 5174.0 .0 5171 5171.0 .0 5167 5167.0 .0 5163 5162.5 - 1.0 5166 5169 5169 5171 5171 5174 5175 5175 5179 5179' 5180 5183 5184 5191" 5193 5196 5196 5196 5164 5168 5169 5168 5170 5173 5173 5175 5176 ~176·. 5117 5179 5180 ····;$1~ 5187 5189 5189 . ;5190 81.0 0.538 4.47 19.32 2,616 2,286 81.2 0.537 5.70 24.62 2,533 2,203 80.4 0.534 8.18 35.36 2.438 2,264 '-' 80.4 0.535 9.39 40.58 2,412 2,255 80.5 0.535 10.60 45.82 2,399 2,262 80.0 0.534 12.06 52.10 2,386 2,316 79.7 0.532 13.29 57.42 2,373 2,239 79.5 0.531 14.48 62.58 2,367 2,311 79.3 0.530 15.61 67.47 2,365 1,907 79.2 0.501 17.57 75.92 2,367 2,991 80.0 0.447 18.84 81.40 2,479 4,561 80.5 0.425 19.52 84.36 2,571 5,344 80.5 0.409 20.14 87.04 2,663 7,344 80.4 0.403 20.29 87.65 ;706 8,174 80.6 0.383 20.58 88.93 2,765 7,006 80.1 0.352 20.95 90.53 2,866 10,539 80.3 0.324 21.16 91.45 2,967 14,823 80.7 0.296 21.37 92.35 3,129 29,000 5165.0 5168.5 5169.0 5169.5 5170.5 5173.5 5174.0 5175.0 2.0 9,327 15.336 254.7 1.0 9,984 15.893 254.4 .0 10,633 16.397 254.4 3:0 10,861 16.512 254.4 1.0 11,236 16.753 254.8 1.0 11,816 17.056 254.8 2.0 12,317 17.228 254.6 .0 13,056 17.398 254.4 5178.5 5181.0 5182.0 ;:'iiå1~îf 5190.0 5192.5 5192.5 ··...··$j93rl:ifV Residual mass Gms> 3.0 14,879 17.538 254.4 81.2 0.272 21.55 93.09 3,577 86,542 4.0 15,481 17.543 254.4 80.8 0.269 21.55 93.12 3,733 137,472 4.0 16,223 17.556 254.9 81.6 0.267 21.57 93.19 3,923 756,270 Ä~~'!~9:°J?it~~~I':Ii~11 g:.á.lW.fif.l!1Jr~Jfi-'£i[fi1j¡'i t¡!fi$J~ ·it~JI~.. 6.0 17,362 17.577 254.6 81.9 0.264 21.59 93.30 4,214 756,270 7.0 17,993 17.565 254.4 81.9 0.263 21.58 93.24 4,381 7S8,270 f¡~it~JH~~¡f§'3~~r~ar.ß~f..r~~¡J-_if:m ;~!~~1J~[~;;r.ir Inc 0.47 Cum mass 18.03 PF-02-067 -' cum 22.15 MB error gm eqv Total 95.70 4.30 0.98 gm % Page 8 WESTPORT TECHNOLOGY CENTER INTERNATIONAL 110 100 -- 90 -- 80 -- a.. ~O -~ ~ : Q) > 860 Q) a:: :~ ~ ~O c C "r'" ~OI a:: ¡¡;: 30 20 10 -: o 0.00 Figure 1. Northstar Slim Tube Run 1, Solvent 1 - 10000000 11.2 Pv % 92.68 Rec I . ..: --- % Recovery -DP -- Rho* 100 .......- Residual -GOR -.-Cum GOR ......-t---- S e ri e s 7 " I . L .y ~~ - - 1000000 175.1 Pv Transition I -- 100000 0::: o C) Single Phases Oil Flow -. 10000 ~ . . ~~,)\ ,,_'" .. r 7" .. - - 1 000 , ·"'~·~~\l'\:-I.~,Mo"':~M·\"~~ . 'f.~" 0.10 0.20 0.30 0.40 0.50 0.60 0.70 0.80 0.90 100 1.00 1.10 1.20 1.30 1.40 1.50 1.60 1.70 Pore Volume Prepared for BP-Alaska 3/1/2004 PF-02-067 Page 9 ) ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL Table 4. Effluent Gas Compositions - Northstar Solvent 1 PVI 0.16 0.32 0.74 0.83 0.96 1.30 1.45 1.64 Solvent 1 Heating Values BTut CF BTU/ CF BTU/ CF BTut CF BTU/ CF BTU/ CF BTU/ CF BTU/ CF BTU/ CF Grossi 1361 1362 1358 1326 1304 1254 1246 1220 1144 Net 1240 1240 1237 1207 1187 1140 1133 1109 1038 MWI 25.484 25.443 25.403 24.930 25.333 24.636 24.461 24.018 I I 22.792 SG 0.8762 0.8749 0.8731 0.8571 0.8707 0.8468 0.8406 0.8259 0.7861 ZSTP 0.9914 0.9914 0.9914 0.9917 0.9918 0.9922 0.9923 0.9925 0.9933 Calc. Critical T & P (OF) -26 -26 -28 -33 -30 -38 ·39 -43 -52 (PSIA) 673 673 673 675 683 687 687 689 695 Component Mole % Mole % Mole % Mole % Mole % Mole % Mole % Mole % Mole % Nitrogen 0.728 0.697 0.738 0.780 0.632 0.726 0.727 0.724 0.717 Carbon Dioxide 5.516 5.427 5.460 5.749 7.562 8.030 7.984 8.075 8.620 Methane 70.589 70.657 71.285 72.426 71.275 72.760 73.173 73.814 74.902 Ethane 8.650 8.697 8.299 7.941 7.861 7.528 7.615 7.532 7.600 Propane 6.072 6.009 5.710 5.293 5.069 4.629 4.559 4.529 4.470 Isobutane 1.123 1.144 1.084 0.972 0.892 0.718 0.700 0.680 0.680 Normal Butane 2.613 2.663 2.552 2.281 2.094 1.613 1.509 1.445 1.430 Isopentane 0.887 0.918 0.908 0.831 0.778 0.574 0.464 0.404 0.376 Normal Pentane 1.089 1.122 1.124 1.046 0.998 0.769 0.627 0.526 0.448 Hexanes 0.994 1.004 1.037 1.004 1.010 0.893 0.789 0.668 0.389 Benzene 0.053 0.051 0.060 0.053 0.061 0.057 0.057 0.047 0.000 Heptanes 0.874 0.878 0.927 0.899 0.940 0.916 0.910 0.811 0.368 Toluene 0.290 0.261 0.244 0.229 0.216 0.216 0.190 0.177 0.000 Octanes 0.431 0.407 0.468 0.426 0.491 0.481 0.536 0.470 0.000 Nonanes 0.080 0.061 0.092 0.065 0.104 0.083 0.135 0.090 0.000 Decanes 0.010 0.004 0.012 0.005 0.016 0.007 0.023 0.008 0.000 Undeeanes 0.000 0.000 0.000 0.000 0.001 0.000 0.002 0.000 0.000 Docecanes 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Tricanes Plus 0.001 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 TOTAL: 100.000 100.000 100.000 100.000 100.000 100.000 100.000 100.000 100.000 Component Wt% Wt% Wt% Wt% Wt% Wt% Wt% Wt% Wt% Nitrogen 0.800 0.767 0.814 0.877 0.698 0.826 0.832 0.844 0.881 Carbon Dioxide 9.526 9.387 9.459 10.148 13.136 14.345 14.365 14.794 16.645 Methane 44.438 44.552 45.017 46.604 45.138 47.382 47.990 49.300 52.722 Ethane 10.206 10.278 9.823 9.577 9.330 9.188 9.360 9.428 10.026 Propane 10.506 10.414 9.912 9.362 8.822 8.286 8.219 8.315 8.648 Isobutane 2.562 2.612 2.481 2.266 2.046 1.695 1.664 1.644 1.734 Normal Butane 5.959 6.083 5.838 5.317 4.805 3,805 3.587 3.497 3.647 Isopentane 2.512 2.603 2.578 2.404 2.217 1.680 1.368 1.214 1.190 Normal Pentane 3.084 3.182 3.193 3.027 2.842 2.252 1.850 1.579 1.418 Hexanes 3.361 3.401 3.519 3.471 3.436 3.124 2.778 2.397 1.471 Benzene 0.162 0.155 0.183 0.166 0.188 0.182 0.182 0.154 0.000 Heptanes 3.436 3.457 3.657 3.615 3.717 3.725 3.730 3.382 1.618 Toluene 1.048 0.946 0.885 0.847 0.786 0.807 0.715 0.680 0.000 Octanes 1.933 1.827 2.106 1.952 2.214 2.231 2.502 2.237 0.000 Nonanes 0.402 0.308 0.467 0.337 0.528 0.430 0.708 0.482 0.000 Decanes 0.054 0.025 0.065 0.028 0.088 0.040 0.136 0.048 0.000 Undecanes 0.003 0.001 0.003 0.001 0.007 0.001 0.013 0.001 0.000 Docecanes 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Tricanes Plus 0.007 0.001 0.001 0.001 0.001 0.002 0.001 0.003 0.000 TOTAL: 100.000 100.000 100.000 100.000 100.000 100.000 100.000 100.000 100.000 Gal/Met Gal/Met Gal/Met Gal/Mct Gal/Mct Gal/Met Gal/Met Gal/Met Gal/Met Condensate Yield ? 6.98 ? 7.00 ? 6.83 ? 6.37 ? 6.24 ? 5.59 ? 5.47 ? 5.20 ? 4.53 Nitrogen Carbon Dioxide Methane Ethane 2.31 2.32 2.22 2.12 2.10 2.01 2.03 2.01 2.03 Propane 1.67 1.65 1.57 1.46 1.39 1.27 1.25 1.25 1.23 Isobutane 0.37 0.37 0.35 0.32 0.29 0.23 0.23 0.22 0.22 Normal Butane 0.82 0.84 0.80 0.72 0.66 0.51 0.48 0.46 0.45 Isopentane 0.32 0.34 0.33 0.30 0.28 0.21 0.17 0.15 0.14 Normal Pentane 0.39 0.41 0.41 0.38 0.36 0.28 0.23 0.19 0.16 Hexanes 0.38 0.39 0.40 0.39 0.39 0.35 0.31 0.26 0.15 Benzene 0.01 0.01 0.02 0.01 0.02 0.02 0.02 0.01 0.00 Heptanes 0.36 0.36 0.38 0.37 0.39 0.38 0.37 0.33 0.15 Toluene 0.10 0.09 0.08 0.08 0.07 0.07 0.06 0.06 0.00 Octanes 0.20 0.18 0.21 0.19 0.22 0.22 0.24 0.21 0.00 Nonanes 0.04 0.03 0.05 0.03 0.05 0.04 0.07 0.04 0.00 Decanes 0.01 0.00 0.01 0.00 0.01 0.00 0.01 0.00 0.00 Undecanes 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Docecanes 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Tricanes Plus 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6.98 7.00 6.83 6.37 6.24 5.59 5.47 5.20 4.53 Prepared tor BP-Alaska 3/1/2004 PF-02-067 Page 10 WESTPORT TECHNOLOGY CENTER INTERNATIONAL Table 5. Slim Tube Properties - Northstar Slim Tube Flood 2 Pore Volume Tube Length Permeability Porosity Flood Injection Rate Linear Velocity 56.24 cc 60.25 ft 17.6 Darcy 40.7 % 1.58 PV/day 95.195 ftlday 0.062 cc/min Sample Description Westport ID Satu rate % Aromatic % Polar % Asphaltene % Original Oil analysis WTC5713.D 66.74 27.53 5.64 0.10 Distill, Slim Tube #2 HCJ777.D 55.99 32.98 10.59 0.43 Prepared for BP-Alaska 3/1/2004 PF-02-067 Page 11 Table 6. Slim Tube 2 Summary - Northstar Slim Tube Flood 2 Solvent 2 WESTPORT TECHNOLOGY CENTER INTERNATIONAL ~ --- Cumulative Incremental Fluid Rho * un vOlume GaR GaR GaR GaR 100 Eluted (ee) % Recovery (ee / ee) (SCF / STBl (ee / ee) (SCF / STB\ 40.5 0.00 0.02 476 2674 493 2770 45.4 0.76 3.42 578 3244 325 1825 49.9 2.09 9.39 476 2674 493 2770 51.4 3.26 14.64 486 2731 528 2964 51.0 4.24 19.03 507 2847 583 3272 .:~~. 2fJlf~Jlffj:!I[~f~rlr·jfJ1iffp·X:ff~10~:I~~[i¡lÈ[~i 51.8 6.44 28.89 526 2952 495 2780 52.1 7.58 33.99 520 2918 467 2623 :2~":" llr4ff~Jff.~~~1~1{-1fJffjl!fi1l~I';fl.!1~RJJ.E?~ff& 49.9 10.20 45.74 498 2795 551 3094 51.3 11.22 50.29 502 2816 498 2798 51.3 '.¡'!1i1:fllll§1f~lfffflj'!~íft~~îJlª¡ fl~fZ.~fi-~!æ~l~§! 51.1 12.30 55.17 500 2807 460 2582 50.5 13.49 60.47 497 2790 458 2573 5Q~ '''J~JJ9Æ1i'''~IM~~ ~1j¡1!@fli&Îj:gWj-~1if~~~:flIWi~JJ 49.7 14.66 65.73 495 2777 427 2399 45.2 15.78 70.78 495 2777 601 3374 43;g .Lç~II~t~«.l'Etfri,~~ 3ii~îij!1ÆKff02~mjf~f!~1'~ 42.2 16.61 74.47 506 2844 838 4704 39.5 17.27 77.45 521 2923 889 4993 :~ ·~r!¡;j!Jr·!!111ll11~~!.ðY~I~¡~£i[f!l~jg~1 29.6 18.36 82.33 555 3118 1722 9667 27.0 18.63 83.55 581 3262 3431 19263 26.1 18.76 84.12 610 3423 5647 31706 .~~~ ·····~tIf!!~~il fr.fi~P'~~;fÆ¥K~tlf!!¥Æ&~~¥ ~J~~~1~~f~~j¡; 25.5 19.04 85.36 657 3689 1392 7818 25.3 19.10 85.65 683 3833 26775 150336 25.2 19.13 85.80 715 4017 45320 254457 ~:r' ii0~~~¡1¡3jfiffjAlIfÆTlt~}~B ðlJf~J~ i'JI¡1f~1B~~ 24.9 19.26 86.35 778 4369 29223 164079 24.8 19.28 86.45 808 4536 13485 75716 ~j~" fid';'fr~t;TPfr~1f'.:¥16i~I~~ :~~J&!!~~ ~FffJ~¡ :Ji{~f~i Total Cum Recovery 21.96 98.58% 1.42% unaccounted mass 0.41 gm Fluid Rho 0.405 0.454 0.499 0.514 0.510 :Q.5W· . 0.531 0.518 0.521 ;0.509 . 0.493 0.499 0.513 '0.513 0.511 0.505 . 0:503 0.497 0.452 0;430 0.422 0.395 0:357 '0.351 0.296 0.270 0.261 iÙ:259 . 0.257 0.255 0.253 0.252 0251 0.250' 0.249 0.248 ~0.249 0.248 RM T (OF) 81.9 79.7 79.8 79.2 79.2 7!J.º 78.6 79.0 78.9 7ð~; 78.8 78.7 79.2 792: ';nÚ' . 79.8 8OÞ' 80.1 79.9 :89)1 . 79.8 79.8 ;80.2 ïj¡:í:3 80.4 80.6 81.1 '~8t~: 80.8 80.8 80.6 80.8 'æ.$ 8Ü' 81.7 80.5 110:~'. 80.6 Oven Temp. (OF) 254.7 255.3 254.9 254.6 254.8 ~:1' 255.2 255.2 255.1 ~.1 254.7 254.8 254.2 253.5 253.5 254.0 ~.2 253.7 254.0 253.9 . 253.5 253.9 ·2fi'.f1 253.7 254.1 253.5 253.5 2$3.E¡: 254.0 253.8 253.6 254.1 2fi.1.1 253.3 253.6 253.5 253.5 253.8 Cum Oil (am) 0.00 0.62 1.70 2.66 3.45 ':3,..84 . 4.37 5.24 6.17 ß.90 . i29 8.30 9.13 9~6ø, 10.01 10.98 11.53 . 11.93 12.85 .3.33" 13.52 14.06 ;14:52' 1.is7 14.94 15.17 15.27 ;':15~ 15.40 15.49 15.55 15.57 .15.59 15.63 15.67 15.69 15.72 15.7i 1: Gas (ml) 22 440 997 1588 2152 2434 2787 3387 3939 4329 4489 5077 5625 :5907 6151 6702 7026 7249 7807 8211 8410 8990 9532: 9596 10196 10826 11435 11828 . 12042 12505 13038 13687 14053 14400 14983 15573 15752 16182 AVG Press åP ( sl (psia) P 5211 -1 5212 1 5208 1 5205 1 5205 0 5204 '0 . 5205 -1 5215 1 5211 1 - 5209 0 5207 2 5208 0 5209 5 , 521 0;J3 . 5208 . - 11 . 5212 13 5213' 12 5211 11 5210 14 5211 14 5211 14 '. 5218 13 5218 - 12 5216 12 5218 13 5213 11 5210 11 5213 9 5214 12 5212 12 5210 14 5208 14 -5208 14 5206 11 5207 13 5209 11 5223 12 5224 7 P _out (psia) 5198 5197 5194 5192 5192 5191' 5193 5201 5200 5195 5193 5194 5193 ·5191 5189 5191 5193 5193 5189 5191 5190 5199 5200 5197 5198 5195 5192 "95 5194 5192 5189 5188 "S187 5187 5188 5188 5203 5207 PJn (psla) 5197 5198 5195 5193 5192 5191 5192 5202 5201 5195 5195 5194 5198 52Ø4 5200 5204 520S 5204 5203 5205 5204 5212 5212 5209 5211 5206 5203 5204 5206 5204 5203 5202 5201 5198 5201 5199 5215 5214 PVI 0.000 0.051 0.100 0.150 0.200 0.222 0.251 0.299 0.350 0.386 0.399 0.450 0.500 0.627 0.550 0.600 0.631 0.649 0.700 0.738 0.750 0.800 0·845 0.850 0.900 0.950 1.000 1.031 1.050 1.100 1.150 1.200 U29 1.250 1.300 1.350 1.361 1.400 TIme 4:17 AM 5:00 AM 5:45 AM 6:30 AM 7:14 AM '7:34 AM 8:00 AM 8:44 AM 9:30 AM 10:02 AM 10:15 AM 11:01 AM 11:47 AM 12:~3 PM 12:34 PM 1 :20 PM 1:48 PM 2:04 PM 2:50 PM 3:23 PM 3:36 PM 4:20 PM 5:01 PM 5:06 PM 5:51 PM 6:38 PM 7:23 PM 7:51 PM 8:08 PM 8:54 PM 9:39 PM 10:24 PM 10:51 P~ 11:10 PM 11:55 PM 12:40 AM 12:50 AM 1 :25 AM Page 12 PF-02-067 Cum mass 17.87 Inc 2.15 Residual Mass» GssSamplas Prepared for BP-Alaska 3/1/2004 WESTPORT TECHNOLOGY CENTER INTERNATIONAL Figure 2. Northstar ST 2, Solvent 2 120 1000000 - - -. IResidu~ - - 100 . . . . . m r=a - - 1 00000 . f Q. 80 Q oð ~ Q) :ë > 0 èñ CJ Q) ras·8% at 1.2pvi I i;: D:: 60 10000 CJ :::Æ ~ co ~ '- oð 0 0 e" 0 ... .. 0 .c ~ . D:: 40 - -Fluid Rho * 100 --- % Recovery - 1 000 -Series2 - DP (psi) 20 )Ji Gas Sampling -GOR (SCF / STB) -+-- GOR (SCF / STB) 0 100 0 0.2 0.6 0.8 1.2 1.4 1.6 1.8 2 Pore Volume Inj. Prepared for BP-Alaska 3/1/2004 PF-02-067 Page 13 ) ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL Table 7. Effluent Gas Compositions - Northstar ST 2 SLIM TUBE SLIM TUBE SLIM TUBE SLIM TUBE SLIM TUBE SLIM TUBE SLIM TUBE SLIM TUBE SLIM TUBE Solvent 2 as Solvent 2 #2 #2 #2 #2 #2 #2 #2 #2 #2 specified as Built PVI 0.22 0.39 0.53 0.63 0.74 0.85 1.03 1.23 1.36 Heating Values BTUI CF BTUI CF BTUI CF BTUI CF BTUI CF BTUI CF BTUI CF BTUI CF BTUI CF Grossi 1231 1302 1357 1346 1352 1324 1217 1178 1177 1089 1090 I Net 1119 1185 1235 1225 1231 1205 1106 1069 1068 986 987 MWI 24.199 25.254 25.098 24.831 24.889 24.352 23.876 23.181 23.229 I I 21.850 21.856 SG 0.8331 0.8692 0.8630 0.8542 0.8556 0.8374 0.8210 0.7979 0.7995 0.7543 0.7545 Z STP 0.9926 0.9919 0.9915 0.9916 0.9915 0.9918 0.9926 0.9929 0.9929 0.9938 0.9938 Calc. Critical T & P (OF) -39 -29 -30 -32 -32 -37 -44 -50 -50 -61 -61 (PSIA) 690 684 672 672 670 671 688 691 692 699 699 Component Mole % Mole '10 Mole % Mole % Mole % Mole % Mole '10 Mole % Mole % Mole % Mole % Nitrogen 0.602 0.573 0.677 0.744 0.793 0.843 0.736 0.731 0.635 0.730 0.738 Carbon Dioxide 8.102 7.567 4.946 4.814 4.621 4.587 7.867 8.013 8.217 8.790 8.780 Methane 72.007 70.004 71.693 71.903 72.540 73.824 74.133 75.302 75.065 76.410 76.397 Ethane 8.305 8.455 8.601 8.689 8.338 8.021 7.542 7.340 7.493 7.580 7.580 Propane 5.485 5.921 5.875 5.973 5.668 5.325 4.471 4.308 4.393 4.210 4.200 lsobutane 0.899 1.101 1.109 1.106 1.048 0.965 0.687 0.636 0.642 0.640 0.636 Normal Butane 2.138 2.556 2.578 2.566 2.440 2.238 1.604 1.458 1.449 1.340 1.370 Iso-pentane 0.296 0.808 0.875 0.866 0.844 0.783 0.317 0.225 0.189 0.090 0.089 Normal Pentane 0.430 0.973 1.068 1. 057 1.046 0.983 0.468 0.339 0.281 0.110 0.110 Hexanes 0.551 0.836 0.961 0.937 0.976 0.943 0.621 0.488 0.448 0.090 0.090 Benzene 0.034 0.034 0.051 0.041 0.056 0.047 0.052 0.037 0.036 0.000 0.000 Heptanes 0.550 0.680 0.833 0.776 0.876 0.837 0.708 0.567 0.550 0.010 0.010 Toluene 0.207 0.131 0.214 0.127 0.195 0.137 0.176 0.123 0.118 0.000 0.000 Octanes 0.310 0.312 0.422 0.349 0.452 0.402 0.470 0.352 0.362 0.000 0.000 Nonanes 0.070 0.045 0.084 0.048 0.093 0.060 0.126 0.074 0.100 0.000 0.000 Decanes 0.012 0.004 0.012 0.004 0.013 0.005 0.020 0.007 0.020 0.000 0.000 Undecanes 0.002 0.000 0.001 0.000 0.001 0.000 0.002 0.000 0.002 0.000 0.000 Dodecanes 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Tricanes Plus 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 TOTAL: 100.000 100.000 100.000 100.000 100.000 100.000 100.000 100.000 100.000 100.000 100.000 Component Wt% Wt% wt% Wt% Wt% Wt% wt% Wt% Wt% wt% wt% Nitrogen 0.697 0.635 0.756 0.839 0.892 0.969 0.864 0.883 0.766 0.936 0.946 Carbon Dioxide 14.735 13.187 8.673 8.533 8.170 8.289 14.501 15.211 15.568 17.705 17.680 Methane 47.740 44.471 45.825 46.457 46.758 48.634 49.813 52.111 51.843 56.103 56.079 Ethane 10.320 10.066 10.304 10.523 10.073 9.904 9.498 9.520 9.700 10.431 10.429 Propane 9.995 10.339 10.321 10.607 10.041 9.642 8.257 8.194 8.339 8.496 8.474 lsobutane 2.159 2.534 2.569 2.589 2.446 2.302 1.672 1.594 1.606 1.702 1.691 Normal Butane 5.136 5.882 5.970 6.006 5.698 5.342 3.904 3.655 3.626 3.565 3.643 lsopentane 0.882 2.309 2.514 2.517 2.446 2.319 0.958 0.700 0.587 0.297 0.294 Normal Pentane 1.283 2.780 3.070 3.071 3.031 2.913 1.414 1.055 0.874 0.363 0.363 Hexanes 1.963 2.852 3.300 3.251 3.379 3.337 2.243 1.813 1.661 0.355 0.355 Benzene 0.109 0.105 0.159 0.128 0.175 0.152 0.169 0.126 0.121 0.000 0.000 Heptanes 2.279 2.700 3.324 3.133 3.526 3.444 2.973 2.452 2.373 0.046 0.046 Toluene 0.787 0.477 0.786 0.470 0.721 0.520 0.678 0.490 0.467 0.000 0.000 Octanes 1.462 1.411 1.919 1. 605 2.076 1.886 2.249 1.736 1.778 0.000 0.000 Nonanes 0.370 0.229 0.432 0.249 0.480 0.315 0.676 0.410 0.553 0.000 0.000 Decanes 0.069 0.020 0.068 0.021 0.077 0.028 0.118 0.045 0.122 0.000 0.000 Undecanes 0.010 0.001 0.008 0.001 0.007 0.001 0.011 0.002 0.014 0.000 0.000 Docecanes 0.001 0.000 0.001 0.000 0.000 0.000 0.000 0.000 0.001 0.000 0.000 Tricanes Plus 0.003 0.001 0.002 0.001 0.003 0.003 0.001 0.002 0.001 0.000 0.000 TOTAL: 100.000 100.000 100.000 100.000 100.000 100.000 100.000 100.000 100.000 100.000 100.000 GallMcf Gal/Mcf Gal/Mcf Gal/Met GallMet Gal/Mcf Gal/Met Gal/Mcf GallMcf Gal/Met Gal/Met Component ? 5.66 ? 6.52 ? 6.83 ? 6.75 ? 6.66 ? 6.25 ? 5.15 ? 4.69 ? 4.72 ? 3.92 ? 3.93 Nitrogen Carbon Dioxide Methane Ethane 2.22 2.26 2.30 2.32 2.23 2.14 2.01 1.96 2.00 2.02 2.02 Propane 1.51 1.63 1.62 1.64 1.56 1.46 1.23 1.18 1.21 1.16 1.15 lsobutane 0.29 0.36 0.36 0.36 0.34 0.32 0.22 0.21 0.21 0.21 0.21 Normal Butane 0.67 0.81 0.81 0.81 0.77 0.71 0.51 0.46 0.46 0.42 0.43 Iso pentane 0.11 0.30 0.32 0.32 0.31 0.29 0.12 0.08 0.07 0.03 0.03 Normal Pentane 0.16 0.35 0.39 0.38 0.38 0.36 0.17 0.12 0.10 0.04 0.04 Hexanes 0.21 0.32 0.37 0.36 0.38 0.36 0.24 0.19 0.17 0.03 0.03 Benzene 0.01 0.01 0.01 0.01 0.02 0.01 0.01 0.Q1 0.01 0.00 0.00 Heptanes 0.23 0.28 0.34 0.32 0.36 0.34 0.29 0.23 0.23 0.00 0.00 Toluene 0.07 0.04 0.07 0.04 0.07 0.05 0.06 0.04 0.04 0.00 0.00 Octanes 0.14 0.14 0.19 0.16 0.20 0.18 0.21 0.16 0.16 0.00 0.00 Nonanes 0.03 0.02 0.04 0.02 0.05 0.03 0.06 0.04 0.05 0.00 0.00 Decanes 0.01 0.00 0.01 0.00 0.01 0.00 0.01 0.00 0.01 0.00 0.00 Undecanes 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Docecanes 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 T ricanes Plus 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Prepared for BP-Alaska 3/1/2004 PF-02-067 Page 14 WESTPORT TECHNOLOGY CENTER INTERNATIONAL Table 8. Dispersion Coefficient Toluene Displaced by N-Pentane at 5200 Psi and 254°F NS 31 Oil Solvent diff» Toluene Data Pentane Data d iff> > Run at : Rate PV/Day 1.85 1.24 K,= K,= Density and Viscosity of the Fluids Density(gm/cc) Viscosity (cp) 0.51 0.2 0.239 0.03 0.271 0.15 vis ratio 0.81 0.58 0.22 0.30 0.17 0.55 vis ratio after Perkins & Johnson SPE 480 Prepared for BP-Alaska 3/1/2004 PF-02-067 0.044 0.032 Page 15 -1 , > I ) ') Addendum to Northstar slim tube report. Slim tube Northstar 3 Solvent 2 y,., N ~ f'lw- ~ The slim tube system was run at the lowest injection rate ever attempted, and represented an extreme test of the equipment's capabilities and integrity. Consequently, a number of heretofore insignificant leaks were reveled that had to be addressed. The necessary fixes were undertaken and the entire system leak tested using low pressure N2. The system was then displaced with Toluene and pressurized to 5200 psi for further leak testing. The permeability of the tube was checked and was still in the 17.6 Darcy range. The tube was prepared for.a live oil flood. The flood was started and a pump seal leak was discovered. The pump was exchanged for a new pump. The data acquisition system was changed due to a hard drive and communication failures. The flood was completed successfully on October 13 at midnight. Incidental data acquired during the flood indicated a linear dispersion coefficient of 0.044 cm2/sec at an injection rate of 1.8 PV/day. The data also indicated a slight change in the tube pore volume. The tube was then prepared for solvent flood with solvent # 2. The flood was initiated by moving solvent through the by-pass for 6 hours, when pressure, flow rates and gas production stabilized. Solvent flow was now diverted through the tube, but it tookl0 hours before the first oil was detected at the densitometer. Even taking into account the slower flow rate, this is almost twice the time normally encountered in our slim tube studies. Normally at 10% pore volume injected we would expect to see fluid coming out, in this instance it took almost half a pore volume. At 12.5 hrs the first oil had progressed through the system to the separator. This was thought to be an unacceptable delay in oil response but no explanation was forthcoming. The run was terminated after 1.75 pore volumes solvent injected. However, the initial delay in oil production resulted in a scant 1.2 pore volume eluted. The tube was further displaced with toluene and the toluene evaporated to generate a "residual oil fraction.". The residual oil fraction represents 2.13% of the original oil in place. A material balance of the system results in an unaccounted mass larger than 6 grams. The system was cooled and closely inspected for indications of leaks to try and explain this errant behavior. The solvent cylinder was also cooled and opened, but no stains, puddles or lumps were observed that could provide a clue to this run's behavior. The system was re-heated and cleaned with hexanes at high temperature. The effluent mixture was cloudy but not tinted. The permeability was re-measured at 20 Darcies, indicating that some blockage had been removed from the flow paths. Unfortunately, none of this provides a reasonable explanation for the results that we saw . We have tried reducing the data on a mass basis but there is mass missing that makes a closing of the mass balance impossible. We saw a similar problem with a volumetric balance. Something is happening in the physical process that we cannot put our hand on. To avoid many of these experimental pitfalls, a slim tube run with these fluids at the same slow flow rates would be better served if the tube had a much larger pore volume than the one in question. Additionally, it might prove beneficial to introduce check valves at the start of the slim tube to prevent backflow of the injected fluids. Northstar ST 3 Solvent 2 110 . - -~-~- ~- --- _~ ':":'~.-_ T ." \ ~_-_-"-_x.---.- ~:~--- . ::;;.:...., ~ _ .. . .,,"L ---=-_ .0.1 ..____L·o· . .~_. 1000000 100 ~ 10 ~~ --- % Recovery -DP -Rho*100 ----Injection Line -GOR P l' ;( 11-/ . / ' /- / J, ./ ~ - 100000 90 D. 80 Q ~ 70 _ Q) > " 8 60 ~ ~ Single Phases on Flow Q) ~ ~ .~. - ,ÌaA.i I ~ . ~ ~I II o 50 Od . .. " r n 1I'f, oð - Ht -".'- - ·_u.,I\_u- ~. .....,..... o .,...... o -# :- 40 ~~ o - .c _ 0:: 30 ~ " ~ - 10000 ~ o C) - 1000 ---"..\,___....t...._ ....ct. .___.. .., _. 1... ~IL. 20 -.~ - 100 o 10 0.00 0.10 0.20 0.30 0.40 0.50 0.60 0.70 0.80 0.90 1.00 1.10 1.20 1.30 1.40 1.50 1.60 1.70 Pore Volume Weslpoft Lab-Res Fluids Figure 3 ST 31.xlsChart 7/22/2003 ') STATE OF ALASKA ) JUN 2 Jl 2005 ALASKA Oil AND GAS CONSERVATION COMMISSIO~Ua~~{;@ rn 8'1 REPORT OF SUNDRY WELL OPERATIÖfJ~~·· 1 . Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 Repair Well 0 Pull TubingD Operation Shutdown D PluQ Perforations 0 Perforate New Pool 0 Perforate [K) Stimulate ŒJ WaiverD OtherD Time Extension 0 Re-enter Suspended WellO 5. Permit to Drill Number: 201-0600 6. API Number 50-029-23009-00-00 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development 0 ExploratoryD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Stratigraphic 0 ServiceŒj 9. Well Name and Number: NS31 10. Field/Pool(s): Northstar Field / Northstar Oil Pool 56.00 8. Property Designation: ADL-312799 11. Present Well Condition Summary: Total Depth measured 11440 feet true vertical 11278.5 feet Effective Depth measured 11309 feet true vertical 11149.0 feet Plugs (measured) IBP removed 03/23/2005 (11309') Junk (measured) None Casing LINER PRODUCTION SURFACE Length 658 10884 3192 Size 7" 29# 13Cr80 9-5/8" 53.5# L-80 13-3/8" 68# L-80 MD TVD Burst 10781 - 11439 10628.7 - 11277.5 43 - 10927 43.0 - 10772.2 45 - 3237 45.0 - 3233.6 8160 7930 4930 Collapse 7020 6620 2270 Perforation depth: Measured depth: 11075-11090,11090-11150,11150-11170, 11184-11198, 11198-11304 True vertical depth: 10917-10932,10932-10992,10992-11012, 11029-11042,11042-11144 SCANNED .JUL 0 7 2005 TubinQ ( size, Qrade, and measured depth): 7" 32# T -95 5-1/2" 17# L80 7" 32# L-80 @ 41 @ 10661 @ 10692 10661 10692 10785 Packers & SSSV (type & measured depth): 7" MCX SSV 7" Baker S-3 Packer 7" Baker SABL-3 Packer 7" Liner Top Packer @ 2005 @ 10604 @ 10730 @ 10781 RBDMS 8Fl JUN 2 2 2005 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11150-11170, 11184-11304 Treatment descriptions including volumes used and final pressure: 892 bbls Seawater, 83 bbls 12% DAD Acid. Tubing Pressure - 1500 psi Prior to well operation: Subsequent to operation: Oil-Bbl o o Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 74857 0 380 83628 0 Tubing Pressure 4874 4795 13 Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD DevelopmentD Service Œ] 14. Attachments: Contact DeWayne Schnorr Printed Name DeWayne Schnorr Æ?Í~ Þ(J~ WAG D GINJŒ] WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 Sundry Number or N/A if C.O. Exempt: 305-078, 305-108 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Petroleum Engineer Signature Phone 564-5174 Date 6/15/05 ORIGINAL Form 10-404 Revised 4/2004 ') ) NS31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/03/05 T/I/O=3600/0/0 ACID TREATMENT - PUMPED DOWN TUBING, 5 BBL METHANOL SPEAR, 5 BBL FILTERED SEAWATER SPACER, 83 BBLS 12% DAD ACID, 842 BBLS HEATED 100* FILTERED SEAWATER FLUSH. 9 BBLS METHANOL CAP. TURN WELL OVER TO PRODUCTION CONTROL TO PUT BACK ON INJECTION PER PROCEDURE. FINAL WHP'S=500NACNAC. ***JOB IN COMPLETE*** 06/05/05 PERFORATED 110901.11150' WITH 2.88" HSD 6SPF 60 DEG PHASED PJ2906 GUNS. MADE TWO 30' RUNS. USED GAMMA RAY TO CORRELATE TO SLB USIT LOG DATED 3-JUL Y-01. DID NOT TAG TO. LOG COLLAR DATA POOR DUE TO TOOL BOUNCING DOWN HOLE FROM TENSION SPIKES CAUSED BY DRY CHROME TUBING. WILL SHOOT REMAINING PERFS 06-06-05. TURN WELL OVER TO TENDER TO PUT ON INJECTION FOR NIGHT. 06/06/05 SHOT 110751-11090' WITH 2.88" HSD 6SPF 60 DEG PHASED PJ2906 GUNS. TIED INTO SLB USIT LOG DATED 3-JUL Y-01, USED GR FOR CORRELATION. COLLAR DATA WAS POOR DUE TO TOLL JUMPING UP HOLE FROM TENSION SPIKES CAUSED BY DRY CHROME TUBING. DID NOT TAG TO TURN WELL OVER TO PLANT. ***JOB IN COMPLETE*** FLUIDS PUMPED BBLS 14 Methanol 450 Seawater 442 Filtered Seawater 83 12% DAD Acid 989 TOTAL Page 1 /- TREE: ABB-VGI 7" 6.5 ksi WELLHEAO:ABB-VGI 13-5/8" 6.5 ksi Multibowl NS31 ') FROM DRLG - DRAFT 13 3/8", 68#/ft, L-80, BTC @3237' ~ Minimum ID = 4.825" @ 10688' SELF ALIGNING MULE SHOE 7", 32#/ft, "]'"..95, ValnTopf'1C rUSIf\]G ¡t): 6,094" '7" F~ N¡PPLE'::, ",·10583' 6$75" II) (OTIS) T' F'¡ NIF)PLE,·"HHi2S' G,ß7S" ID (OTIS) T' n,N NIPPLE:, "'10639' 5.'?!:;" Ie) (OTIS)- 7" R NIPPLE, @ 10709' & 10755': 5.963" 10 (OTIS) 7" RN NIPPLE, @10767' 5.77" 10 (OTIS) 7" WLEG, @10785' 6.184" 10 (OTIS) ! 95/8", 53.5#/ft L-80, BTC-M @10927' FEHtR:\lDJ8...MAAr' ÆFLC:X3 <RAIT(5'22J01) [TJe-h Leg: ffiCDJLBT] AN3..EAT"KP~ N:íe: Rter to Ftcxi.db1 œ fa- hstaica ~ d:ta htia Fèrf - ~ 45EFòNerJ:í, I-M<; R:rarëfut 54"; H]e: ,42'; R-æe: 72 Œg _SZE ffi= Nlffi/lILrvÐ Nlffi/IIL 1\¡[) Q:n'~ D\lE 4.5 5 1118f-11Df 11CJæ-1114<+ Qn 7/14121)1 4.5 5 1115:1-11170 1ŒE2-11012 Qn 11/19'aXJ1 PBTO @11356' MO 11195' TVO TO @11439' ~ DATE 6/4/01 9/10/01 11/?0/01 02/15/05 O~/On/Of) REV. BY COMMENTS AGK Initial Diaqram EMF Inserted TVD Depths EMF Add Perf LV Actual Completion JAF/TI H FISH ANn nFRRI~ III!.. Q ~ ~ '1KB. ELEV = 56' ~B-BF. ELEV = 40.6' BASE FLANGE ELEV = 15.4' HQR SSSV @ 2005' MD 7" H Nipple, ID :::: !:¡,S7(:;" GS' "17# 'Tubíns¡ Taíl wi f"H::::S Self rnulo 81')00 "'10688', ¡D:::: .Jet c:ut ""1 06e:t MD Baker SABL-3 PACKER 6.00" 10 @10730' MD 10579' TVD 7" LINER TOP @10781' MD 10629' TVD 6.184" 10 7", 29#, 13Cr Northstar WFI I : NS31 API NO:50-029-23009-00 BP Exploration (Alaska) ¿,,<{) / - t' 07 0 bp ) ) Date: 05-17-2005 Transmittal Number: 90177 BPXA WELL DATA TRANSMITTAL Enc10sed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091 SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type GAMMA RAY TIE NS31 02-10-2005 SCH 10466 10967 IN/JEWELRY LOG; ~ ~ í II a~~ /~ !tJa1M:~~ . Please SIgn an~Jeturn one copy of this transmIttal. Thank You, Vi James H. Johnson Petrotechnical Data Center RECEIVED MAY 1 7 200!:! ^'a~"a Oil & G ' C~ '" "" " . , ,ðS 011;.. L()IIïIf ~!\lOn Anthol'ôß(¡ Attn: Howard Oakland (AOGCC) Attn: Kristin Dirks (DNR) SCANNED JUN 1 7 2005 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AI< 99519-6612 ) ) Ø/- !J6() "'~·~.Î~I'!. .:( ::~~~J "'''] ~'I'''' " '. 'j , "\~"'\ !; :í~.dJ d '.:;u,~""'" -..::.iI r~:'J :1 'I !:1'."'21 :r ~l~=J FRANK H. MURKOWSKI, GOVERNOR AIßASKA OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 SCANNED MAY 2 fj 2005 Re: NS 31 305-108 Dear Mr. Francis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission' s petrole~m field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on th rd day following the date of this letter, or the next working day if the 23rd day fal on holiday or weekend. A person may not appeal a Commission decision to Su erior ourt unless rehearing has been requested. , DA TED this ~y ~005 Encl. bp ) ) ... dutJt~ O'~ 0 BP Exploration (Alaska) Inc. ". 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519·6612 (907) 561·5111 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: RECEI\IEf) APR 2 8 Z005 April 22, 2005 Alaska Oil & Gas Cons. Commission Anchorage Re: Sundry Notice for NS31 to Add Perforations BP Exploration Alaska, Inc. proposes to shoot additional perforations in the NS31 gas injection well. The additional gas injectivity these perforations will provide will help increase field gas handling capacity. The procedure includes the following major steps: Type Slickline Electric Line Slickline Work Description Pull SSSV, Drift/taQ wI dummy Qun Perforate 75' of Ivishak 11,075' - 11,150' MDrkb ' / Run SSSV Sincerely, ~~l !E'¿;yY\W:; Mic~ael J. Frar¡(¢i~E~j Senior PetroleY'm Engineer BPXA, ACT, Northstar ~ ·','t.... . '., riP! r !: f\J I ~ . I· " f .,_ Alter Casing Change Approved Program Abandon D D D VJGA-·, 4 (l..q /2.ðO$ ) STATE OF ALASKA ) ~~EI\(ED ALASKA 'OIL AND GAS CONSERVATION COIVII\I1ISSION PR Z~'~ APPLICATION FOR SUNDRY APPRQ~A~Gas Cons. Commission 20 AAC 25.280 ^nchorago Operation Shutdown D perforate[!j' ~4K WaiverD Plug Perforations D StimulateD Time Extension D Perforate New Pool D Re-enter Suspended Well D 4. Current Well Class: 5. Permit to Drill Number: 201-0600 ,..--' Repair Well Pull Tubing Suspend D D D Other 0 1. Type of Request: 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. Development D Exploratory D 11. Presen1 Total Depth MD (ft): 11440 Casing Total Depth TVD (ft): 11278.5 StratigraphicD Service ŒJ /' 9. Well Name and Number: NS31 /' 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11356 11139.4 Size MD TVD 6. API Number ~. 50-029-23009-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.00 KB 8. Property Designation: ADL-312799 Length Plugs (md): 11198 Burst Junk (md): None Collapse LINER PRODUCTION SURFACE Perforation Depth MD (ft): ~l $' ~ t 0 11150 - 11170 11184 - 11198 Packers and SSSV Type: 7" Liner Top Packer 7" Baker SABL-3 Packer 7" Baker S-3 Packer 7" MCX$SSV ,;. " .I¡ 12. Attachments: 658 10884 3192 top bottom top bottom 7" 29# 13Cr80 10781 11439 10628.7 11277.5 8160 7020 9-5/8" 53.5# L-80 43 10927 43.0 10772.2 7930 6620 13-3/8" 68# L-80 45 3237 45.0 3233.6 4930 2270 Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10992 - 11011.6 7 " 29 # L-80 10692 10785 11025 - 11039.3 7 " 32 # T-95 41 10692 Packers and SSSV MD (ft): 10781 10730 10604 ' S\jI-N 2005 Description Summary of Proposal [!] Detailed Operations Proç¡ram 0 BOP Sketch 0 14. Estimated Date for Commencing Operation: 13. Well Class after proposed work: May 3, 2005 Exploratory 0 DevelopmentD 15. Well Status after proposed work: Oil D Gas D Plugged D Abandoned D /" GINJIX] WINJD WDSPLD Prepared by Garry Catron 564-4657. Michael Francis Service ŒJ 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: WAGD Contact Printed Name Signature Plu ntegrity. Other:@;~ Subse ent rm F\tI~ired Approved 7. ) JJ Michael Francis ~>--M IJ. ~ $;S4't,.~ I P, IE. Commission Use Only mis ion so that a representative may witness Title Phone Petroleum Engineer 564-4240 4/19/05 BOP TestD Mechanciallntegrity Test D Sundry Number: ~3Ø5-(O<g Location Clearance D BY ORDER OF r/lrL'" THE COMMISSION Date:.:) /'1 ();;;) \. RBOMS BFl MAYO 3 2005 Form 10-403 Revised 11/2004 ORIGINAL SUBMIT IN DUPLICATE BP Exploration (Alaska) North!=;t==-r WFI .1 .: NS31 API NO:50..0?9-?3009..00 7'''~29#~ 13Cr I; ~ªJÇØr'SABL-3 PACKER 'á.ÒÒíi'lD @10730' MD 10579' TVD 7" LINER TOP @10781' MD 1.06.29' TVD e.184" ID cut ""10692' MD ~. ...~er S-3 Packer -10604' MD 1;";' I¡! '.55:17# Tubing ,¡<II Stinger : ,t,,'; ¡,1"~~~f, aHgl1¡I"Ig mule shoe to ",,1 Of388', ,····~...r\X~~8PPG DIESEL FREEZE '''''''¡'' """"PROTECTION AT +1- 3000 " " 7" R Nipple 32U @ -2005' MO/TVD , ,... qØMMENT:$ Irdtiar,Ð\äãràfòU.· .. ." .. Ádd:<Þer( 'Jñs~ea··TVD Ð~pths 'Ätld ·~ø.rf . : Aduat l;omoletlon DÂTE 6/4lo1- 1t14t01 9/1:0l01 :'f1120f(l1. O~J1~~1~a( :c REV. BY A~R ~M - EMF EMF LV l PBTO @11356' MO 11195' TVO TO @11439' J ,g A:m:R\'OCNs..M8>R( ÆFLœ (RAJf(8Z2i\)1) [T&hl..cy ŒCD.IlBl] .MG.EAT1(pFHT: N:te: RíertoRoir::lk:nlJ3fal1staX:a ¡:at dt3 ~ Fèf - ~ 4!ffiRwerJ:i, !-Me; R:rØrëtb'c ~~ Hfs.42'; Rm!]2~ æ; s:F NI&WUD NIERIÞl "M) ~ 0\1E 04.5 5 11181-11:Ð1 'tUB-11144' Qn 71W.m1 45 5 111~-1117IJ 1œJl·11012 QJ1 11n92XJ1 :1· ..... 7" R NIPPLE, @ 10709!."....:;/.,J, ;&10755': 5'963.1~:~ 7" RN NIPPLE, @10767',., ..., ~'~'¡'';¡';':i:< :', 5.77" ID (OTIS)''''''':'''' ;'" 7"...6.~1~~~i~lg~f~;~.' '..-"i:~.·.i 95/8".. 53.5#/ft,J .~ L-80, BTC-M @10927",,, .. ~ ~; 7" R NI¡;')¡:~LE, "~1O*ß~~; ~¡~~~~76" II) (OTIS) T' n NIPPLE, '''10G.28' ~).a'?6" 10 (OrIS})",w¡""'''' 7", 32#/ft, T-HG. Vz~rnT()p HC rUf:3INí:? ID: ().m~4" ,;:J 13 3/8",; 68#/ft ., i;; L-80, BTC @3237' FROM DRLG-DRAFT :,;~,,~.::. TREE: ABB-VGI 7" 6.5 ksl WELLHEAO:ABB-VGI 13-5/8" 6.5 ksl Multibowl ELEV = 56' KB-BF. ELEV = 40.6' BASE FLANGE ELEV = 15.4' ~. iì{Æ·' A 'IT Œ .' U II ¡ .' '0...1 1 ) lUJÍfÎÌ I~ !ÆA ~ 1%8' .~~ r~;' .fÆß· U ¡ . ¡: J .r· . n J) U ;' , 'L..:.=I U ~ \..:::..i' ; , ) AIfA.SIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 JvD L:- fJ loD Re: NS31 Sundry Number: 305-078 Dear Mr. Francis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days'after written notic~ of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd d y following the date of this letter,. or the next working day if the 23rd day falls on a ôl day or weekend. A person may not appeal a Commission decision to Superior 0 unless rehearing has been requested. '"""" nce" y, ~ DATED thi:3/ day of March, 2005 Encl. -"-'.' . . ",-iE-=-¡ ¡"PR-' '"j <'¡ 9005 ;StR",,",Nhu;;.L.·.'Ì ,...!. _, t_ bp ) ') .,. ,\1"'11. --....~...,,.~~. .~~ ~~. ·'i"'- BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519·6612 (907) 561-5111 March 29, 2005 :J.pl'"' oføv RECEIVED MAR 3 0 200S Alaska Oil & Gas Cons. COmnissioø Anchorage Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS31 to Acidize/Water Wash (Ivishak) BP Exploration Alaska, Inc. proposes to acidize and water wash the NS31 well. A RWO was recently completed on NS31. Since coming back on line after this RWO, injectivity is less than it has been in the past. /.. The procedure includes the following major steps: . Bullhead HCI based acid treatment and displace with water. .,/". . Return well to gas injection Sincerely, ~~rf~ Senior Petro~'~m Engineer BPXA, ACT, Northstar ;. ¡---, ("\ ~ ¡.. I "'. \.~, f ~\ I i \ f\ ._. Abandon o \i...i c.A Wu ¿OD S ) STATE OF ALASKA ) ~ .J/.?,... ECEIVEI ALASKA OIL AND GAS CONSERVATION COMMISSION :.s.Ý'orr %5- MAR 3 0 2005 APPLICATION FOR SUNDRY APPROVALA'askaOil&G 20 AAC 25.280 as Cons. Comm Anchor aye Operation Shutdown D PerforateD .-""/ Waiver D Other 0 Plug Perforations D StimulateŒ] Time Extension D Perforate New Pool D Re-enter Suspended Well D 4. Current Well Class: 5. Permit to Drill ~.. .umber: 201-0600 / D Suspend D D RepairWell D D Pull Tubing D :1' 1. Type of Request: Alter Casing Change Approved Program 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 11. Total Depth MD (ft): 11440 Casing Total Depth TVD (ft): 11280.8 Development D Exploratory D Stratigraphic D Service ŒI ('-- 9. Well Name and Number: NS31 ",/' 10. Field/Pool(s): Northstar Field 1 Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11356 11141.7 MD TVD 6. API Number /' 50-029-23009-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.00 KB 8. Property Designation: ADL-312799 ~/ Length Size Plugs (md): 11198 Burst Junk (md): None Collapse LINER PRODUCTION SURFACE Perforation Depth MD (ft): 11150 - 11170 11184 - 11198 Packers and SSSV Type: 7" Top Packer 7" HES HRQ SSV 7" Baker SABL-3 Packer 12. Attachments: 671 10884 3192 top 7" 29# 13Cr80 10768 9-5/8 Inch 53.5 Lb L-I 43 13-3/8 Inch 68 Lb L-8 45 Perforation Depth TVD (ft): 10994 - 11013.9 11028 - 11041.6 bottom top 11439 10618.2 10927 43.0 3237 45.0 Tubing Size: 7 " bottom 11279.8 10774.5 3233.6 Tubing Grade: ,L..SÐ- í~q$ 'yJ(J,.f-\ 10781 2037 10730 4930 7930 8160 Tubing MD (ft): 44 2270 6620 7020 ~ 32Jf Packers and SSSV MD (ft): 10785 Description Summary of Proposal [!) Detailed Operations Proç¡ram D BOP Sketch D 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Well Class after proposed work: April 4, 2005 Exploratory D DevelopmentD 15. Well Status after proposed work: Oil D GasD PluggedD AbandonedD WAG D GINJIli] / WINJD WDSPLD Prepared by Garry Catron 564-4657. Michael Francis Service ŒJ Date: Contact Michael Francis ~"'tP # :f--- "'<I " ,. t£ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Printed Name Signature Title Phone Petroleum Engineer 564-4240 3/29/05 Appr Sundry Number: 30Ç-o'/ ?' BOP TestD Mechanciallntegrity Test D Location Clearance D Other: \o~ 4-04-, BY ORDER OF ~~J' ~,r THE COMMISSION Date: IV 1/ {)::> RBDMS BFllJ PR 0 1 2005 "- Form 1 0-403 Revised 11/2004 OR¡GII~AL SUBMIT IN DUPLICATE TREE: ABB-VGI 7" 6.5 ksi WElLHEAD:ABB-VGI 13-5/8" 6.5 ksi Multibowl ') ") NS31 FROM DRLG-DRAFT 133/8", 68#/ft, L-80, BTC @3237' ~ 7", :1;?#lft, T-D5, VarnT'op HC TUBING I£): (>.O~;)4" 7" R NIPPl.E, "'1058:,' (;,876" II) (OTIS) 7" R NIPPLE, ,,,10628' S.B·7!5" II) (OTIS) 7" RN N!PPLE, ,-'10(539' 6.'7[,)" ID (UTIS) 7" R NIPPLE. @ 10709' j & 10755': 5.963" ID (OTIS)~ 7" RN NIPPLE. @10767' 5.77" ID (OTIS) 7" WLEG, @10785' ~!' 6.184" ID (OTIS) 9 5/8", 53.5#/ft l-80, BTC-M @10927' FB=R:R\TCN8.Mtm( ÆFlO3 CHAIT(5'Zà'01) [flfJ-h l..crJ CHOJ.A.S1] .AJ'G.EATlt:PÆff: N::te: R:ferto R'cxldb1 œf(r nsm:a ¡:at dta rma Fèf - O'aga 4S:6 Rw6"J!, ~ R:n:trëfut 5f'; J-t:je: .42~ A"ase: 72 ~ SZE SF ~AI.. M) NlER/Æ l\ID Qn'S::¡z D\1E 4.5 5 11181 -1ß):f 11<Jæ-1114<f Cþ'1 7/14':4X)1 4,5 5 111!i1-1117U 1ŒBZ-11012 Q:n 1V192JJ1 PBTD @11356' MD 11195' TVD TD @11439' j DATE 6/4/01 7/24/01 9/10/01 11//0/01 ( O?f15/?O REV. BY AGK è:Mf EMF EMF LV COMMENTS Initial DiaQram Add Perf Inserted TVD Depths Add Perf Actual Completion c: ~ !III.. Q ~ )KB. ELEV = 56' )SF. ELEV = 40.6' i'3ÀSE FLANGE ElEV = 15.4' 7" R Nipple 32# @ -2005' MD/TVD ~ 6.8PPG DIESEL FREEZE PROTECTION AT +1- 3000 BøIŒr' 8<~Pa(:I«.,¡r -10E>04' MD 5.!5" 1 '(# 'TlJbin~:~ 'T';:;,il Sfjnf:~(:~r, ID::::4.aø2" wI HES Sølf <~lignino mulc! shoe to '~1 0688', ID""4.825" Jøt cut '~"1 0692' MD Baker SABL-3 PACKER 6.00" 10 @10730' MO 10579' TVD 7" LINER TOP @10781' MD 10629' TVO 6.184" ID 7", 29#, 13Cr Northstar WFI I : NS31 API NO:50-0?9-?3009-00 BP Exploration (Alaska) .. STATE OF ALASKA ') ALASKA ,..JL AND GAS CONSERVATION COlvllV1ISSION CE'VED REPORT OF SUNDRY WELL OPERATIO~ MAR t·1 2005 .. .. n 0·, Ra......1a~~Cons. commlmJ A\aska t 't..---O er doc orege TIme Extension 1. Operations Performed: D Abandon D Alter Casing D Cha nge Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 312799 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Condu ctor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): 181 Repair Well D Plug Perforations D Stimulate 181 Pull Tubing D Perforate New Pool D Waiver D Operation Shutdown D Perforate D Re-Enter Suspended Well 56' 11440 11281 11356 11198 199' 3192' 10884' 747' 4. Current Well Class: D Development D Exploratory D Stratigraphic 181 Service 5. Permit To Drill Number: 201-060 6. API Number: 50-029-23009-00-00 99519-6612 9. Well Name and Number: NS31 10. Field / Pool(s): Northstar Unit feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 199' 199' 4260 2590 13-3/8" 3237' 3234' 4930 2270 9-5/8" 10927' 1077' 7930 6620 7" 10692' - 11439' 10544' - 11280' 8160 7020 SCANNED MAR 2 4. 2n05 11150' - 11304' 10994' - 11146' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 7",32# T -95E V AM TOP 10688' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" SABL-3 Packer 7" SABL-3 Packer, 7" HRQ SSSV Nipple 10604' 10730',2005' Treatment description including volumes used and final pressure: RBDMS BFL MAR 1 4 2005 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: D Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram 15. Well Class after proposed work: D Exploratory D Development 181 Service 16. Well Status after proposed work: D Oil D Gas D WAG 181 GINJ D WINJ D WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Dan Kara, 564-5667 304-412 Printed Name Sondra Stewman ~} . Sigflature ~ê~-,-C>-r- Form 10-4.04Revised 04/2004 Title Technical Assistant ÓhK\ G f~~~L _ ¡r-.{2. P~ared By Name/Number: Dat~.~_fC:8~dra Stewman, 564-4750 Submit Original Only TREE: ABB-VGI 7" 6.5 ksi WELLHEAD:ABB-VGI 13-5/8" 6.5 ksi Multibowl ~) NS31 FROM DRLG-DRAFT 13 3/8", 68#/ft, L-80, BTC @3237' ~ T', ::¡;?#lfi, ·T-~3b, VarnTop HC TUBING D; 6.094" 7" R NIPPLE., '",10683' s.an:;" ID (OTiS) T' R NIPPLE, ··"'1062(3' E).8'7~)" ID (OTiS) 7" RN NIPPLJ?::, ''''j 063~)' S.!!:)" ID (UriS) 7" R NIPPLE, @ 1 0709' ~ & 10755': 5.963" ID (OTIS~ 7" RN NIPPLE, @10767' 5.77" ID (OTIS) 7" WLEG, @10785' 6.184" ID (OTIS)- 9 5/8", 53.5#/ft L-80, BTC-M @1092T /' F£fRR\TQ\Js..JI...M.R{ ÆFLffi <RAJT(5'22I01) [Tle-h Leg CHCIlJU3l] Af\G£ATTIPÆÆ N:te: R:te- to RaiJ:fu1 [Bfa- tistaiŒI ¡:at Œia htia R:rf - Q-ag:!: 48:E R>Ne- J:t, t-M<; R:n:tréfu1: 54"; HJe: .42'; Ftase: 72 da;:¡ SZE s:F NlffiJIIL rvÐ NlffiJIIL TvD Q:rl9:¡z D\lE 4.5 5 1118f-11:Df 11aæ-11144 Q:n 7/141:ID1 4.5 5 111EO-11170 1ŒBZ-11012 Q:n 11/19AD1 PBTD @11356' MO 11195' TVO TO @11439' j DATE 6/4/01 7/24/01 9/10/01 11/?0/01 0?/15/?0( REV. BY AGK I::Mr EMF EMF LV COMMENTS Initial DiaQram Add Perf Inserted TVD Depths Add Perf Actual Completion c B ... Q ~ )KB. ELEV = 56' KB-BF. ELEV = 40.6' BASE FLANGE ELEV = 15.4' T r.ç Nipple 32# @.¿ '-2005' MD/TVD ~ 6.8PPG DIESEL FREEZE PROTECTION AT +/- 3000 Bcd<er S-::\ Paçh:ør '-10604' fv1D S.b" 17#TubinqT<:1il , ID~~4.g92" wI HES Sølf ølíqníno rn'Ùle :~,hoe ''''j Oe8S', ID"·"4.B2f5" Jot cut ."..¡ 0692' MD Baker SABL-3 PACKER 6.00" ID @10730' MD 10579' TVD 7" LINER TOP @10781' MD 10629' TVD 6.184" ID 7", 29#, 13Cr Northstar WFI I : NS31 API NO:50-0?9-.?3009-00 BP Exploration (Alaska) ) ) Well: Field: API: Permit: NS31 Northstar Unit 50-029-23009-00-00 201-060-00 POST-RIG WORK 02117/05 PULLED BALL & ROD, PULLED RHC PLUG, BAILED 1/2 GALLON OF MUD FROM ON TOP OF IBP @ 11,0341 SLM. 02/18/05 BAILED APPROX 4 GALLONS OF MUDISLUGGETS FROM 11,005' SLM TO 11,0451 SLM. 02/19/05 BAILED APPROX 3 GALLONS OF MUD FROM 11,045 TO 11,047' SLM. NO SLUGGETS RECOVERED. 02/20105 BAILED APPROX 3 GALLONS OF HEAVY MUD FROM 11,045 TO 11,047' SLM 02/21/05 BAILED APPROX 4 GALLONS OF MUD FROM 11,045 TO 11,0481 SLM. 02/22/05 BAILED APPROX 1 GALLON OF MUD FROM 11,0481 SLM, RECOVERED A 111 X 111 PIECE FROM THE CHEMICAL CUTTER FISH. 02/24/05 BAIL SLUGGETSIFISH IBPISET 711 MCX (POST RWO). RIH WI 4.6511 GR TO 110421 SLM. BAILED APPROX. 4 MORE GAL OF THICK PACKED MUD FROM 110421 TO 11048' WITH 4 BAILER RUNS. NO SLUGGETS RECOVERED 02/25/05 BAIL FILL (POST RWO) CONTINUED FROM 2/24105 WSR - RECOVERED APPROX. 3 GAL OF SOLIDS FROM 110047' TO 11052' SLM. PICKING UP SMALL WEDGE SHAPE PIECES OF COPPER, O-RINGS, AND GASKET MATERIAL. AFTER 5 BAILER RUNS, RIH WI 4.5" LIB TO 110481. NO MARKS. RIH WITH 4 PRONG GRAB. POOH. LAY DOWN FOR NIGHT. 02/26/05 BAIL FILL POST RWO. CONTINUED FROM 2/25105 WSR. BAILED FROM 110501 TO 110521 SLM. APPEARS TO BE LEDGE AT 11048' SLM. RECOVERED APPROX. 4 GAL OF SOLIDS, 3 LARGE COPPER METAL CHUNKS, AND 2 BIG PIECES OF A 3" OD RUBBER SEAL. NO SIGN OF SLUGGETS. 02/27/05 SWAP OUT SLlCKLlNE DRUM. MADE 2 - 311 X 10' PUMP BAILER RUNS TO 110521 SLM. RECOVERED 1 1/2' OF FILL. RIH WITH 3" PUMP BAILER WITH BRAIDED LINE FINGER BASKET ON BOTTOM (NO FLAPPER) TO 11052' SLM. RECOVERED NOTHING. RIH WITH 3.78" LIB TO 11047' SLM. IMPRESSION OF METAL CHUNKS. RIH WITH 411 MAGNET TO 11048'. RECOVERED 2 PIECES OF METAL. NS31 Page 2 ') 02/28/05 BAILED FILL AND METAL. RECOVERED LARGE WEDGE SHAPE CHUNK OF METAL OF WHAT APPEARS TO BE PART OF JET CUTTER. 03/01/05 RIH WITH 4.5" LIB DECENTRALIZED TO 11047' SLM. 3" HALF MOON IMPRESSION SHOWING OBSTRUCTION ON LOW SIDE. NO OTHER MARKS. RIH WITH 2.8" LIB DECENTRALIZED TO 11047' SLM. MARKS AT 6 O'CLOCK AND AT 12 OICLOCK. LAY DOWN EQUIP FOR CRANE MAl NT. 03/02/05 BAIL METAL DEBRIS AND FILL (POST RWO) CONTINUED FROM 3/1/05 WSR. CRANE SERVICING AND REPAIRS COMPLETED @ 15:00. RIH WITH 2 5/8" HYD BAILER W/ 3.47'1 FINGER BASKET TO 110481 SLM. DISK SHEARED, NO RETURNS. RIH WITH 2.5"3 PRONG WIRE GRAB TO 110501 SLM. OOH WITH GRAB - 1 PRONG BENT BACK, 1 BOWED, AND 1 STILL STRAIGHT. OVERPULLS THRU TT. RIH WITH 3" PUMP BAILER WITH MODIFIED 4.5" BRAIDED LINE JUNK BASKET SHOE TO 110521 SLM. RECOVERED -21 OF FILL, WIRES BENT UP. ) ) BP.EXPLOHATION Operations Surnmary Report Page tot 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS31 NS31 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 1/5/2005 Rig Release: 6/1/2001 Rig Number: Spud Date: 4/26/2001 End: Date Frorn - To Hours Task Code ··NPT Pha.se Descriptionot Operations 1/8/2005 06:00 - 18:00 12.00 MOB P DECOMP Warm Up Cold Start Engine wi Tioga-Install New Batteries-Start Engine-Energize Service Module 1/9/2005 05:30 - 06:00 0.50 MOB DECOMP PJSM fl Rig Start Up 06:00 - 18:00 12.00 MOB DECOMP Attempt to Start Cold Start Engine(Would Not Start)- Troubleshoot Through Nabors Mechanic on Beach (No Mechanic on Island Due to Severe Weather Shutting Down Transportation-Start Cold Start Engine-Coordinate Energizing Gas Line in Pipe Rack wi Ops-Engergize Gas Line-Start Mac Air Heater 1/10/2005 05:30 - 06:00 0.50 MOB DECOMP PJSM fl Rig Start Up 06:00 - 18:00 12.00 MOB DECOMP Troubleshoot Gas Valve in Pipe Rack wi Ops-Prep SCR Room-Clear & Clean Motor Room-Prep fl Glycol Transfer to Radiators-Recieved Gas fl Pipe Rack (Ops Assisted in Confirming Gas Regulator on Rig Functioning Properly)-Fix Gas Leak Outside of Service Module-Fire Mac Air Heater & Warm Up Rig. 1/11 /2005 05:30 - 06:00 0.50 MOB P DECOMP PJSM fl Rig Start Up 06:00 - 18:00 12.00 MOB P DECOMP Start Air Compressor-Start Rig Moving System-Stage Glycol Motor Room 1/12/2005 00:00 - 05:30 5.50 MOB P DECOMP Night Watch Gen Set 05:30 - 06:00 0.50 MOB P DECOMP PJSM wi Rig Crew-ATP fl Shoveling Out Rig wi Crew & Ops 06:00 - 18:00 12.00 MOB P DECOMP Add Anti-freeze to #1-2-4 Rig Engines-Dig Snow Out of Area Around Rig-Prep Boiler Water Feed System-Install Batteries in Invertor 18:00 - 00:00 6.00 MOB P DECOMP Night Watch Gen Set 1/13/2005 00:00 - 05:30 5.50 MOB P DECOMP Night Watch Gen Set 05:30 - 06:00 0.50 MOB P DECOMP PJSM 06:00 - 18:00 12.00 MOB P DECOMP Dig Out Snow f/ Around Remainder of Substructure-Install Antifreeze in #4-5 Rig Engines-Inspect Boilers & Air Tank in Motor Room-Install Brushes in #1 & #2 Mud Pump Traction Motors-Test Run #1-2-4-5 Rig Engines-Took Cold Start Offline-Prep to Set Rig Mats Between Flowlines. State Boiler inspector - check boilers. 18:00 - 00:00 6.00 MOB P DECOMP Prepare Lift Plan fl Rig Mats Between Flowlines-PJSM wi All Personnel Involved wi Lift-Install Rig Mats Between Flowlines 1/14/2005 00:00 - 05:30 5.50 MOB P DECOMP Set Remainder of Rig Mats wi AIC Loader-Night Watch Gen Set 05:30 - 06:00 0.50 MOB P DECOMP PJSM 06:00 - 00:00 18.00 MOB P DECOMP Brush Fire Tubes on Boilers-Change Out 2" 'Y' Valve & Knife Valve on #2 Boiler-Function Test Hydraulic Moving System on Substructure & Service Module-Lay Herculite fl Substructure-Place Tioga Portable Heater on G&I wi AIC Crane-Build Enclosure Around 13800 Volt Connection & Apply Heat wi Tioga in Prep to Unhook 1/15/2005 00:00 - 12:00 12.00 MOB P DECOMP Prep Mud Pumps fl Assmebly-Heat 13800 Transformer Connection fl Disconnect-Newly Arrived Crew Attended Northstar HSE Training 12:00 - 18:00 6.00 MOB P DECOMP Unhook 13800 Connection fl Pipe Rack to G&I-Misc. Commisioning of Rig. 18:00 - 00:00 6.00 MOB P DECOMP Move Substructure Into Position w/ Service Module 1/16/2005 00:00 - 06:00 6.00 MOB P DECOMP Shim Service Module-Slide PUTZ to Substucture-Hook Up Mac Air Heater to Substructure-Install Stairs 06:00 - 12:00 6.00 MOB P DECOMP Install Mud Hoses Through PUTZ-C/O Gas Line-Remove Printed: 2/14/2005 9:25:00 AM ) ) BP EXPLORATION OperatipnsSult1lt1ary. Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS31 NS31 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 1/5/2005 Rig Release: 6/1/2001 Rig Number: Spud Date: 4/26/2001 End: Date From - To Hours Task Code NPT Phase Description of Operations 1/16/2005 06:00 - 12:00 6.00 MOB P DECaMP Exhaust Cover 12:00 - 18:00 6.00 MOB P DECOMP M/U High Pressure Mud Line Through PUTZ-Run Electrical Cables fl Service Module to Doghouse MCC Room 18:00 - 00:00 6.00 MOB P DECaMP Install Gaskets & Door Seals in Boilers-Move 7 Inch Tubing fl South End of Service Module 1/17/2005 00:00 - 06:00 6.00 MOB P DECaMP PJSM-Hook Up H20 to Boiler & Hot Well-Install Stair Landing fl G&I-Continue Moving 7 Inch Tubing 06:00 - 12:00 6.00 MOB P DECaMP PJSM-Start Boilers (3 Inch Valve on #2 Boiler Bad, Bleed Pressure & Replace)-Replace Gasket on #2 Boiler MacDonald Valve-Remove Ice & Snow fl Rig Floor-Run Electrical Cables to Rig Floor-Fire #2 Boiler 12:00 - 18:00 6.00 MOB P DECaMP PJSM-Continue Plugging in Electrical Lines to Rig-Install Steam Traps in Service Module Heaters 18:00 - 00:00 6.00 MOB P DECaMP PJSM-Repair #1 Boiler Feed Pump-Prep Mud Ends on Both Mud Pumps-Work on Main Valve fl # Boiler 1/18/2005 00:00 - 06:00 6.00 MOB P DECOMP - Repair main valve on # 1 boiler. - Install feed pump on # 1 boiler. - Test fresh water lines in sevice complex. - Continue removing snow & ice from rig floor. 06:00 - 12:00 6.00 MOB P DECaMP - Put # 2 boiler on line. - Test steam lines wi air - cia & repair same. - Hang PLC panel for TD. - Prep pad for skidding rig. 12:00 - 18:00 6.00 MOB P DECOMP - Continue to locate & repair air & steam leaks throughout rig. 18:00 - 00:00 6.00 MOB P DECOMP - Thaw main water line from piperack to rig. R/U 2" jumper hose & fill day tank. - Remove drag chain for replacement. 1/19/2005 00:00 - 06:00 6.00 MOB DECaMP - Test water lines in sub & on pumps. Bring on line. - Test rig floor hydraulics & bring on line. - Function test VLE & operate. - Remove super sacks of snow from rig floor via VLE. 06:00 - 12:00 6.00 MOB DECaMP - Inspect man rider & tugger lines. - Remove covers to drawworks blower vents. - Install skate rail & function test skate. 12:00 - 18:00 6.00 MOB DECaMP - Bring TD service loop to rig floor. - Maintenance & repair to valves in pits. - Electricians working on PLC & control panel for TD throughout day. 18:00 - 00:00 6.00 MOB DECaMP - cia man rider lines. - Unhang blocks. - R/U pick-up slings on blocks & move TD to clear rotary table. - A TP I PJSM wi Island personnel & rig crew for rig move. - Training rig crews on moving system - skid rig towards NS-31. 1/20/2005 00:00 - 07:00 7.00 MOB P DECaMP - PJSM - Skid rig towards NS-31. 07:00 - 15:00 8.00 MOB P DECaMP - A TP & training wi both rig crews wi Northstar & Anchorage Mgt teams. 15:00 - 19:00 4.00 MOB P DECaMP - PJSM - Skid & spot rig over NS-31. 19:00 - 00:00 5.00 MOB P DECaMP - Clear rig floor. - Slip drilling line. - Pull quill from swivel & remove swivel seals. - Check suction valves in pits. 1/21/2005 00:00 - 06:00 6.00 MOB P DECOMP - Replace swivel seal. - Inspect degasser. Printed: 2/14/2005 9:25:00 AM ) ') BP EXPLORATION Operations Summary Report Page 3 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS31 NS31 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 1/5/2005 Rig Release: 6/1/2001 Rig Number: Spud Date: 4/26/2001 End: Date From- To Hours Task Code NPT Phase Description of Operations 1/21 /2005 00:00 - 06:00 6.00 MOB P DECaMP - Test S/W line in G & I & rig w/ air & bring on S/ W to G & I. - Hang swivel. - Grease standpipe valves. 06:00 - 12:00 6.00 MOB P DECOMP - Hook up emergency showers in pits. - Grease blocks & rollers. - Hook up derrick climber. - Test mud lines from trip tank & lines in pits to G & I w/ air. - Magnaflux & inspect swivel connection & quill shaft. - Grease crown. 12:00 - 18:00 6.00 MOB P DECOMP - Berm around outside of rig. - Check electrical connections in derrick for service loop. - Test degasser motor. - Electricians working on rD PLC throughout day. 18:00 - 00:00 6.00 MOB P DECaMP - Crew change - new crews arrived late on two separate flights. 1 st crew of 5 arrived & attended Nortstar orientation, UIC, NPDES, EMS & Polar Bear training. All hands new to Northstar & 33-E. Toured rig & cleaned up rig. 2nd crew of 7 arrived later & attended the same training & had a brief tour of rig before crew change. 1/22/2005 00:00 - 12:00 12.00 MOB P DECaMP - M/U quill shaft to swivel. - Hang TD & attach to bottom rail - Torque bolts. - Remove ice & clean L pits. - Install Auto Driller. 12:00 - 00:00 12.00 MOB P DECOMP - Cotinue torquing up bolts on TO. - Hang hydraulic service loop for TD. - Continue cleaning L pits. - Clean pits 1 & 2. - Install pipe handler on TD. 1/23/2005 00:00 - 12:00 12.00 MOB P DECOMP - Continue R/U pipe handler on TO. o C/O lines on cellar bridge cranes. - Remove washpipe & goose neck. - Remove paddles & links from drag chain. - Inspect pipe handling equip't. - Swap to cold start & Island personnel repaired gas valve. - Clean rig floor. 12:00 - 00:00 12.00 MOB P DECaMP - Hang TO electrical service loop & terminate cables in derrick. - C/O 6" liners in #1 mud pump. - Install screens on shakers. - C/O union on goose neck. 1/24/2005 00:00 - 12:00 12.00 MOB DECaMP - Hang swivel goose neck & wash pipe. - Check pre-charge on Koomey unit. - Install seats & valves in #2 mud pump. - Grease plug valves. - Service & test degasser & desander pumps. - Level sevice complex. - Terminate electrical on TD service loop. 12:00 - 00:00 12.00 MOB DECaMP - Continue terminating electrical on TD service loop. - Hang kelly hose. - C/O valves in shaker room & pits as needed. - Remove drillers side finger board from derrick. o Clean rig. - Epoch hooking up & calibrating monitors. Printed: 2/14/2005 9:25:00 AM ) ') Bp·EXPLORATION Operations:Suml11ary Repprt. Page 4of10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS31 NS31 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 1/5/2005 Rig Release: 6/1/2001 Rig Number: Spud Date: 4/26/2001 End: Date From- To Hours Task Code NPT Phase 12:00 - 00:00 12.00 MOB P DECOMP - Hang drillers side finger board in derrick. - Cut off 391' of drilling line. o Repair gun lines & valves & clean pits. o Troubleshoot electrical hook-up on TD. o Grease plug valves on cement line. o Install & calibrate Epoch monitors. - Prep ram blocks for BOP's. DECOMP - Continue troubleshooting electrical hook-up on TD. o Continue cleaning pits. o Install clean out cover on L pits. o Install bails on TD. - Drying out TD traction motor to determine operability. DECOMP 0 Inspect pipe handling equip't. o Complete thorough inspection of derrick - all zones. - Replace lights in derrick. o Continue drying out TD traction motor. - Test caustic mixer & lines. DECOMP - Troubleshoot TD. Traction motor operable. o Disconnect water line to old cement unit. - Hook up S/W line to rig from piperack & pressurize system. o Moving S/W around in pits checking valves & lines. o Weld toe board back on monkey board. Toe board had to be removed to accommodate previous Canrig TD. o Repairing & replacing water valves in shaker room & pits. DECOMP 0 Continue replacing & repairing valves in pits. o Service centrifuge. o Test super choke control valve. o R/U lines to squeeze manifold. o Repair light fixtures on rig floor. o Continue to troubleshoot TD electronics & motor. o Calibrate H2S & LEL system. - Clean rig. DECOMP - Test H2S & LEL alarms - all good. - Install drag chain. o Clean rig. o Remove TD traction motor. DECOMP 0 Remove TD traction motor. o Install drag chain & paddles. o Clean pits. - Review ATP wi Co. Rep, Tool Pusher, Rig Crew, AIC, & Ops for removing TD motor & raising new motor to rig floor wi crane. Perform operation. DECOMP 0 Install TD traction motor. - Clean rig. DECOMP - Continue TD traction motor installation. o Install duct work. - Hook up electrical to motor & blower. - Set TD back in track & hook up block & oil to gear box. - Hang kelly hose & bails on TD. DECOMP 0 Function test TD - Train personnel in pits & shakers. - Bring tubing handling equip't to rig floor. - Clean rig. 1/25/2005 00:00 - 12:00 12.00 MOB P 12:00 - 00:00 12.00 MOB P 1/26/2005 00:00 - 12:00 12.00 MOB P 12:00 - 00:00 12.00 MOB P 1/27/2005 00:00 - 12:00 12.00 MOB P 12:00 - 00:00 12.00 MOB P 1/28/2005 00:00 - 12:00 12.00 MOB P 12:00 - 00:00 12.00 MOB P 1/29/2005 00:00 - 12:00 12.00 MOB P Printed: 2/14/2005 9:25:00 AM ') ) BPEXPLORATION Operations Summary Report Page 5 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS31 NS31 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 1/5/2005 Rig Release: 6/1/2001 Rig Number: Spud Date: 4/26/2001 End: Date From - To Hours Task Code NPT Phase Description of Operations 1/30/2005 00:00 - 12:00 12.00 MOB P DECOMP - Fill swivel wi gear oil. - Trace out Koomey line. - Train personnel on pipe elevator. - Hook up lines to freeze protect manifold. - Bring 7" NSCC protectors to rig floor. - Clear gas buster vent. - Remove short bails. - CIO bearings on VLE cart. - Stencil tugger & ANSI warnings. - Load pipeshed wi test jt & LJ. 12:00 - 00:00 12.00 MOB P DECOMP - Put rope in derrick for pull back & tie off. - Function test pump & chart recorder. - Locate parts for bell nipple. - Check vac line going to trip tank. - Repairing wash down pump in shaker room. 1/31 12005 00:00 - 01 :00 1.00 KILL P DECOMP - Accept rig @ 00:01 on 1-31-05. - Bring on S/W to pits & G & I. 01 :00 - 18:00 17.00 PULL P DECOMP - Build 1200 bbls 9.5 ppg brine wi 2% KCL. - R/U compensator controls. - Hang long bails. - Top off swivel wi gear oil. - Repair hydraulic leak on TD. - Test pop offs on mud pumps. - Thaw out frozen mud line. - Inspect lifting devices on rig. 18:00 - 19:00 1.00 WHSUR P DECOMP - Set & pull TWC to verify TWC would screw into hanger after modifications. 19:00 - 21 :00 2.00 WHSUR P DECOMP - Remove S riser from tree & secure in cellar. 21 :00 - 23:30 2.50 WHSUR P DECOMP - Test trip tank transfer line ( 110 psi) from rig to G & I. Did not test. Replace leaking valve & re-route line to bypass leak. 23:30 - 00:00 0.50 PULL P DECOMP - Reverse circ freeze protect from tubing @ 1.3 BPM 80 psi. 2/1/2005 00:00 - 01 :00 1.00 PULL P DECOMP - Circ out fz protect long way @ 1.3 BPM 40 psi. 01 :00 - 04:30 3.50 PULL P DECOMP - Circ 9.5 ppg brine @ 6 BPM 1100 psi through choke & gas buster. IBP holding & no gas. 04:30 - 05:00 0.50 PULL P DECOMP - Monitor well 05:00 - 07:30 2.50 WHSUR P DECOMP - Saw piece of metal banding in BPV profile. Attempt to fish out. Went down hole. - Set TWC wi dry rod & test to 500 psi via annulus. 07:30 - 10:30 3.00 WHSUR P DECOMP - Blow down lines. - ND tree & set back on stand. - Drain & secure control lines. 10:30 - 19:00 8.50 WHSUR P DECOMP - NU BOPE. - Hydril tech inspected stack. - Install 7" on top; Blind shear in center; 7" variable on bottom. - NU bell nipple, choke & kill lines, & turnbuckles. 19:00 - 00:00 5.00 WHSUR P DECOMP - Testing BOPE to 250 I 4800 psi. Witnessing of test waived by Jeff Jones--AOGCC Field Inspector ( waived due to Phase weather conditions. ) 2/2/2005 00:00 - 03:30 3.50 WHSUR P DECOMP - Testing BOPE equipment to 250 /4800 psi. 03:30 - 06:00 2.50 WHSUR N SFAL DECOMP - Koomey line to lower rams failed. Notified Control Room & ACS Spill Tech. Classified as non-process leak. - Clean up Hydraulic Fluid from secondary containment. Small amount from gravel at edge of cellar. Printed: 2/14/2005 9:25:00 AM ) ) BP EXPLORATION Operations Surnmary> Re.port Pagè60f 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS31 NS31 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 1/5/2005 Rig Release: 6/1/2001 Rig Number: Spud Date: 4/26/2001 End: Date From- To Hours Task Code NPT Phase Description of Operations 2/2/2005 03:30 - 06:00 2.50 WHSUR N SFAL DECOMP - Change out Koomey line. 06:00 - 09:00 3.00 WHSUR P DECOMP - Testing BOPE equipment to 250 I 4800 psi. 09:00 - 12:00 3.00 WHSUR P DECOMP -R/U Lubricator to pull TWC. Tested to 500 psi. -Pull TWD & RID Lubricator. 12:00 - 13:30 1.50 PULL N DPRB DECOMP -P/U Landing Joint & Attempt to pull 7 inch tubing. Tubing would not pull. -Worked tubing wi 600K (String Wt. 355k wlo TD) several times. wi no success. -Set slips on Landing Joint wI 45K over string weight. 13:30 - 17:00 3.50 PULL N DPRB DECOMP -Spot Wireline Unit & Bring tools to floor. -R/U to RIH wi Gauge Ring & Junk Basket 17:00 - 21 :00 4.00 PULL N DPRB DECOMP -RIH wi 5.81 Gauge Ring & Junk Basket to 10762' WLM. -POOH wi GR & JB. Recovered one bow spring centralizer blade fl previous logging run. 21 :00 - 23:00 2.00 PULL N DPRB DECOMP -P/U Chemical Cutter and prepare to RIH. 23:00 - 00:00 1.00 PULL N DPRB DECOMP -RIH wi Chemical Cutter on Wireline. 2/3/2005 00:00 - 00:30 0.50 PULL N DPRB DECOMP -RIH wi Chemical Cutter, CCL & E-Line Jars t/10688'. 00:30 - 00:45 0.25 PULL N DPRB DECOMP -Space Out Chemical Cutter wi CCL & Fire Cutter @ 10,688' WLM. 00:45 - 05:00 4.25 PULL N DPRB DECOMP -POOH wi Chemical Cutter-Anchors Hanging Up on Collars While POOH-Cutter Stuck @ SSSV (2037'). 05:00 - 09:00 4.00 PULL N DPRB DECOMP -Attempt t/ Jar Cutter Free wi E-Line wi No Success. 09:00 - 09:30 0.50 PULL N DPRB DECOMP -RID Wireline Sheave & R/U 7 Inch 350 Ton Elevators. 09:30 - 11 :30 2.00 PULL N DPRB DECOMP -Attempt t/ Pull 7 Inch Tubing wI 600K (80% Tensile Yield) wi No Success. 11 :30 - 12:00 0.50 PULL N DPRB DECOMP -R/U E-Line Sheave in Preperation t/ Pull Off Rope Socket. 12:00 - 13:30 1.50 PULL N DPRB DECOMP -Pull E-Line Free fl Rope Socket wi 4400 Ibs-SWL & Rig Wt. Indicators Matched-Left Chemical Cutter, CCL & E-Line Jars in Hole. 13:30 - 19:00 5.50 PULL N DPRB DECOMP -Wait on Slickline to Finish Operations on NS07-Commence Mobilization of Tools fl Deadhorse. 19:00 - 00:00 5.00 PULL N DPRB DECOMP Mobilize Tools fl Deadhorse-Rig Up on NS31 wi Schlumberger Slickline Unit 2/4/2005 00:00 - 01 :30 1.50 PULL N DPRB DECOMP -R/U Slickline Unit & MIU Overshot wi 1.375 Grapple & GR Release Tool in Prep to Fish Chemical Cutter, CCL & E- Line Jars Stuck @ 2037' (SSSV) 01 :30 - 02:00 0.50 PULL N DPRB DECOMP -Latch Fish wi Grapple-Jarred Down 4 Hits & Fell Free-Verified Fish by Weight Increase 02:00 - 02:30 0.50 PULL N DPRB DECOMP -Jarred Off Fish-POOH wi GR Tool 02:30 - 03:00 0.50 PULL N DPRB DECOMP -Redressed GR Tool To GS Tool to Allow Upjarring on Fish 03:00 - 03: 15 0.25 PULL N DPRB DECOMP -RIH wi Overshot, GS Tool, Spangs & Jars-Latched Fish @ 2037' 03: 15 - 03:30 0.25 PULL N DPRB DECOMP -Jarred Fish-Fish Pulled Free wi 250 Ibs Over String Wt.-Left 75-100 Ibs. of Fish in Hole 03:30 - 03:45 0.25 PULL N DPRB DECOMP -POOH wi Fish 03:45 - 04:15 0.50 PULL N DPRB DECOMP -PJSM on Handling Fish @ Surface (Potential Release of Toxic Gas)-Pulled Fish Into Landing Joint & Verified That Cutter wI Left in Hole-Pulled Fish (Head, 2" Sinker Bars, E-Line Jars,CCL & Shooting Adapter-Total Length 16') Out of Landing Joint-Left Safe ESIC Housing, Firing Mech & Cutter Assembly in Hole (17.5 feet) 04: 15 - 08:30 4.25 PULL N DPRB DECOMP -Lay Down Fish & Redress Fishing Tools to Attempt to Latch Remainder of Shooting Adapter (1 11/16 X 16")- Wait Printed: 2/14/2005 9:25:00 AM ) ) BP EXPLORATION Operations Summary. Report Pa.ge 7 of to Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS31 NS31 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 1/5/2005 Rig Release: 6/1/2001 Rig Number: Spud Date: 4/26/2001 End: Date From -To Hours Task Code NPT Phase Description of Operations 2/4/2005 04: 15 - 08:30 4.25 PULL N DPRB DECOMP onGrapple to Be Brought From Deadhorse. 08:30 - 09:00 0.50 PULL N DPRB DECOMP -Land Tubing on Hanger & RID 350 Ton Elevators 09:00 - 10:30 1.50 PULL N DPRB DECOMP -RIH wi Overshot, GR Tool, Spangs & Jars-Latched Fish @ 2023' -Sheared GR Tool-POOH 10:30 - 12:30 2.00 PULL N DPRB DECOMP -Redressed GR Tool To GS Tool to Allow Upjarring on Fish-RIH wi Overshot, GS Tool, Spangs & Jars-Latched Fish @ 10719' (Fish Fell fl 2023')-POOH to 2023'-Jarred Fish Through SSSV-POOH to 200' 12:30 - 15:00 2.50 PULL N DPRB DECOMP -PJSM on Handling Fish @ Surface (Potential Release·of Toxic Gas)-Pull Fish t/ Floor & UD (Anchors Hung Up In Landing Joint Resulting In Landing Joint Having t/ Be Backed Out & Pulled Out Of Well While Pulling Fish Below It)-Retrieved Anchor & Safety Head-Chemical Tube wi Centralizers, Catalyst Sub, Severing Head & Centralizer Left In Hole 15:00 - 19:00 4.00 PULL N DPRB DECOMP -Mobilize Fishing Tools fl Deadhorse 19:00 - 20:30 1.50 PULL N DPRB DECOMP -RIH wi Overshot, GR Tool, Spangs & Jars-Tagged Fish @ 10764-Fish Fell Free to 11065' (Top of Sluggit on IBP)-Latched Fish @ 11065' 20:30 - 21 :30 1.00 PULL N DPRB DECOMP -POOH wi Fish fl 11065' t/ 200' 21 :30 - 22:30 1.00 PULL N DPRB DECOMP -PJSM on Handling Fish @ Surface (Potential Release of Toxic Gas)-Island Lost Sea Water Supply to Pipe Rack (20 Minutes to Blow Down Line)-Pull Fish to Floor-Chemical Tube wi Centralizers Retrieved-Catalyst Sub, Severing Head & Centralizer Left in Hole 22:30 - 00:00 1.50 PULL N DPRB DECOMP Discussed Options wi PE, Schlumberger & Drilling Engineer-Mobilize Tools fl Deadhorse 2/5/2005 00:00 - 01 :30 1.50 PULL N DPRB DECOMP -Mobilize Box Tap fl Deadhorse-Discuss Running LIB-Decision Made t/ Run LIB 01 :30 - 03:30 2.00 PULL N DPRB DECOMP -RIH wi LIB, Sinker Bars wi Centralizers, Spangs & Jars-Tagged @ 11079'-POOH-1.15 Circle In Middle of LIB 03:30 - 10:00 6.50 PULL N DPRB DECOMP -RIH wi 3.5 Box Tap, Sinker Bars wi Centralizers, Spangs & Jars-Tag Fish @ 11 080'-Latch Fish (Chemical Cutter & Centralizer) & POOH (Pull Slow to Avoid Dropping Fish)-UD Fish 10:00 - 11 :30 1.50 PULL N DPRB DECOMP -M/U 5.95" GR/JB Assembly-RIH t/ 10767' 11 :30 - 12:00 0.50 PULL N DPRB DECOMP -POOH fl 10767' wi 5.95 GR/JB Assembly 12:00 - 13:00 1.00 PULL N DPRB DECOMP -RID Slickline Unit 13:00 - 14:30 1.50 PULL N DPRB DECOMP -R/U E-Line Unit 14:30 - 15:30 1.00 PULL N DPRB DECOMP -M/U Schlumberger Free Point Tool on E-Line 15:30 - 19:00 3.50 PULL N DPRB DECOMP -RIH wi Free Point Tool-Verify Pipe 100% Free @ 3000' & 1 0700' 19:00 - 20:00 1.00 PULL N DPRB DECOMP -POOH wi Free Point Tool f/10700' 20:00 - 21 :30 1.50 PULL N DPRB DECOMP C/O E-Line-M/U Jet Cutter 21 :30 - 00:00 2.50 PULL N DPRB DECOMP RIH wi Jet Cutter on E-Line to 10700' (CCL Malfunction @ 8500'-Schlumberger Troubleshot & Regained Signal-Continued RIH) 2/6/2005 00:00 - 01 :30 1.50 PULL N DPRB DECOMP -Latched onto Tubing wi 350 Ton Elevators-P/U to 480K (46" Stretch)-Tie In @ 10692' wI CCL-Fire Jet Cutter-Pipe Free-Up Wt. 360K 01 :30 - 03:00 1.50 PULL N DPRB DECOMP -POOH wI E-Line-R/D E-Line Unit 03:00 - 03:45 0.75 PULL P DECOMP -R/U Circulating Head-Prepare Sweep-Prepare tIlnject Dirty 9.5 Brine Printed: 2/14/2005 9:25:00 AM ) ) BP EXPLORATION Operati ons ·Su mmary ··aep()rt PageS· of1 0 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS31 NS31 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 1/5/2005 Rig Release: 6/1/2001 Rig Number: Spud Date: 4/26/2001 End: Date From - To Hours Task Code NPT Phase Description·of Operations 2/6/2005 03:45 - 05:00 1.25 PULL P DECOMP -Circulate Sweep Surface t/ Surface-12 BPM-1500 PSI-6800 Stks Total 05:00 - 06:30 1.50 PULL P DECOMP -Circulate Clean 9.5 Brine Surface t/ Surface-8 BPM-700 PSI-6450 06:30 - 07:00 0.50 PULL P DECOMP -Blow Down Lines 07:00 - 10:30 3.50 PULL P DECOMP -Pull Tubing Hanger t/ Floor-UD Landing Joint-R/U t/ Pull 7" 29# NSCC Tubing wI Single Joint Compensator 10:30 - 21 :30 11.00 PULL P DECOMP -POOH wI 7" Tubing-Spooled Control Line t/ 2034'-Recovered 50 Clamps & 2 Stainless Steel Bands-UD SVLN-POOH wI 7" Tubing t/ 6700' 21 :30 - 22:00 0.50 PULL P DECOMP -Load AIC Bunk Trailer wI 7" Tubing fl Pipe Shed-38 Joints 22:00 - 00:00 2.00 PULL P DECOMP -POOH wI 7" Tubing t/ 6090'-Up WT =180K 2/7/2005 00:00 - 05:30 5.50 PULL P DECOMP -POOH wI 7" Tubing-269 Joints + 13.2' Stub-Hole Fill Correct 05:30 - 07:00 1.50 PULL P DECOMP -Clean Rig Floor-Unload Pipe Shed 07:00 - 09:00 2.00 BOPSUP P RUNCMP -R/U to Test BOPE-Grease Choke Manifold-Drain Stack 09:00 - 11 :00 2.00 BOPSUP P RUNCMP -Attempt to Test BOPE-Test Plug Leaking-Troubleshoot Problem-Pressure Up to 250-4800 PSI 11 :00 - 15:00 4.00 BOPSUP P RUNCMP -Test BOPE-Tested Upper & Lower Pipe Rams to 250 PSI Low&4800 PSI High-Test Annular to 250 PSI Low & 3500 PSI High-Test Blind Rams to 250 PSI Low & 4800 PSI High f/5 Minutes Each-Test Witnessed by AOGCC Inspector 15:00 - 16:00 1.00 BOPSURP RUNCMP -Blow Down Choke & Kill Lines-Blow Down All Test Equipment 16:00 - 20:00 4.00 RUNCOMP RUNCMP -Load Pipe Shed in Prep for Running 7" Vam Top HC Completion-Slickline Waiting on 8.535" GR/JB 20:00 - 21 :30 1.50 RUNCOMP RUNCMP -R/U Slickline wI 8.5" Gr/JB-RIH to 1200'-POOH (8.5" GR to Large fl 53.5# 9 5/8-Created Excessive Up Wt. Due to Swab Effect-Correct Size Drift fl 53.5# 9 5/8 is 8.379") 21 :30 - 23:00 1.50 RUNCOMP RUNCMP -Load Pipe Shed in Prep for Running 7" Vam Top HC Completion-Slickline Waiting on 8.379" GR 23:00 - 00:00 1.00 RUNCOMP RUNCMP -RIH wI 8.38 GR/JB-Load Pipe Shed wI 7" Vam Top HC Completion 2/8/2005 00:00 - 00:30 0.50 RUNCOMP RUNCMP -RIH wI 8.38" GR/JB-Continue Prep 7" Vam Top HC Completion 00:30 - 01 :30 1.00 RUNCOMP RUNCMP -Tag @ 10670' WLM wI 8.38" GR/JB-POOH wI Slickline-Continue Prep 7" Vam Top HC Completion 01 :30 - 02:30 1.00 RUNCOrvP RUNCMP -RID Slickline-Continue Prep Completion Tubing 02:30 - 00:00 21.50 RUNCOtvP RUNCMP -Continue Loading Pipe Shed & Prepping 7" 32# T-95 Vam Top HC Completion Tubing-Clean Threads, Drift & Strap Tubing-Vam Hand Inspecting Treads -Functioned Test Fuel Gas Line Emergency Shutdown & Adjacent Well Emergency Shutdown 2/9/2005 00:00 - 04:30 4.50 RUNCOrvP RUNCMP -Continue Loading Pipe Shed & Prepping 7" 32# T-95 Vam Top HC Completion Tubing-Clean Threads, Drift & Strap Tubing-Vam Hand Inspecting Treads 04:30 - 05:00 0.50 RUNCOrvP RUNCMP -PJSM wI Rig Crew, Nabors Casing, Vam Ace & Baker on Running 7" 32# T-95 Vam Top HC Completion 05:00 - 05:30 0.50 RUNCOrvP RUNCMP -Shut Down Operations fl Mealtime (All Personnel Needed to Run Tubing) 05:30 - 12:00 6.50 RUNCOrvP RUNCMP -RIH wI 7" t-95 Vam Top HC Completion t/ 2780' 12:00 - 00:00 12.00 RUNCOrvP RUNCMP -RIH wI 7" t-95 Vam Top HC Completion fl 2780' to 9390' -Up Wt.=31OK -Dn Wt.=306K 211 0/2005 00:00 - 03:00 3.00 RUNCOrvP RUNCMP -RIH wI 7" 32# Vam Top HC Completion-Tag 7" Tubing Stump Printed: 2/14/2005 9:25:00 AM ) ) BP EXPLORATION Operations.. Sum mary.. Re.port Pägt39 .of 1 0 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS31 NS31 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 1/5/2005 Rig Release: 6/1/2001 Rig Number: Spud Date: 4/26/2001 End: Date From-To Hours Task Code NPT Phase Description of Operations 2/1 0/2005 00:00 - 03:00 3.00 RUNCOMP RUNCMP wI No/Go X-O -Up Wt=368K -Down Wt=346K 03:00 - 04:00 1.00 RUNCOMP RUNCMP -Space Out Completion wI Muleshoe 15' In Cut Off Stub-Muleshoe Depth 10691.55' SLM 04:00 - 05:00 1.00 RNTBHG P TUBHGR -M/U Hanger & Landing Joint-Land Tubing Hanger-RILDS-Test Hanger Seals to 6500 PSI (OK) 05:00 - 05:30 0.50 RNTBHG P TUBHGR UD Landing Joint-Clean Rig Floor 05:30 - 06:30 1.00 RUNCOMP RUNCMP -RID Tubing Tongs & Compensator 06:30 - 07:30 1.00 EVAL P OTHCMP -R/U Schlumberger Slickline Unit 07:30 - 08:30 1.00 EVAL N MISC OTHCMP -Secure Rig & Muster Crew Per Rig Evacuation Procedure Due To Fire Alarm On Location-Rig Loader Caught On Fire Due To Short In Cab 08:30 - 10:00 1.50 EVAL P OTHCMP -M/U 4.70 OD Drift & RIH To 11069' -Tight Spot @ 10693' (New WLEG-4.825") 10:00 - 14:00 4.00 EVAL P OTHCMP -M/U GR/CCL & RIH To Confirm Spaceout-POOH wI GR/CCL 14:00 - 17:00 3.00 EVAL P OTHCMP -Down Load Data fl GR/CCL & Fax To ODE -Prepare To N/D BOPE 17:00 - 18:00 1.00 DHEOP P OTHCMP -RIH wI RHC Plug To 2008' (R-Nipple fl SSSV)-Lost Plug-POOH -Called PE Gerry Boyles fl Technical Advice 18:00 - 18:30 0.50 DHEOP P OTHCMP -RIH wI GR Fishing Tool & POOH wI RHC Plug 18:30 - 19:00 0.50 DHEOP P OTHCMP -Remove Pins fl RHC Plug 19:00 - 21 :30 2.50 DHEOP P OTHCMP -RIH wI RHC Plug To 10642' WLM-Set In RN Nipple-POOH-R/D Slickline Unit 21 :30 - 22:00 0.50 WHSUR P OTHCMP -Install TWC & Test To 750 PSI 22:00 - 00:00 2.00 WHSUR P OTHCMP -N/D BOPE -Drain Stack-Pull Riser-Pull Turn Buckles-N/D Choke & Kill Lines-RID Koomey Lines 2/11/2005 00:00 - 02:30 2.50 WHSUR OTHCMP -N/D BOPE-Set Back In Rack & Secure 02:30 - 05:30 3.00 WHSUR OTHCMP -N/U Tree-Test Tubing Head Adapter & Tree to 6500 PSI (OK) 05:30 - 06:30 1.00 WHSUR OTHCMP -P/U Lubricator & Pull TWC-UD Lubricator 06:30 - 11 :00 4.50 DHEOP OTHCMP -R/U Freeze Protect Manifold In Cellar-Pressure Test Lines To 3000 PSI (OK)-Pump 180 BBL Of Corrosion Inhibited Seawater (EC1124) Down IA @ 3 BPM -Volume Needed To Cover 3000' To Packer 11 :00 - 16:00 5.00 DHEOP OTHCMP -R/U & Pump 180 BBL Heated Corrosion Inhibited Diesel (CRO-408) Down IA @ 1 BPM wI 1100 PSI 16:00 - 17:00 1.00 DHEOP OTHCMP -U-Tube Diesel Into Tubing @ 3 BPM -Volume To Freeze Protect to 3000' -Tubing=108 BBI -IA=70 BBL 17:00 - 17:30 0.50 DHEOP OTHCMP -Drop 1 7/8 Ball & Rod-Pressure Test Surface Lines To 6000 PSI wI Dowell Pumping Unit 17:30 - 18:30 1.00 DHEOP OTHCMP -Pressure Up Tubing To 5800 PSI-Set Packer-Hold Pressure fl 30 Minutes (OK) -John Crisp wI AOGCC Waived Witness Of MIT 18:30 - 20:00 1.50 DHEOP OTHCMP -Bled Tubing To 2000 PSI-Pressured Up IA To 3000 PSI & Held 5 Minutes To Verify Packer Set-Bring IA Pressure To 5800 PSI f/30 Minutes (OK) -Initial Tubing Pressure wI IA @ 5800 PSI=3148 20:00 - 00:00 4.00 WHSUR OTHCMP -Install BPV -Remove Upper Annulus Drilling Sweep & Reinstall Annulus Printed: 2/14/2005 9:25:00 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) ) BPEXPLORATION Operations Summary Report . Page 10 of 10 NS31 NS31 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 1/5/2005 Rig Release: 6/1/2001 Rig Number: Spud Date: 4/26/2001 End: 2/11/2005 20:00 - 00:00 From - To Hours Task Code NPT Phase 4.00 WHSUR OTHCMP Valve -Change Out Bails & Elevators f/7" Tubing To 5" Drill Pipe -Release Rig fl NS31 @ 2359 hrs Feb 11, 2005 Description of Operations Printed: 2/14/2005 9:25:00 AM ) ) ~o!- [)!cÒ Date: 02-16-2004 Transmittal Number: #91588NS31 ~ I G 6& ) 0 ë¡J- ~" BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojohnsojh@bp.com Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type NS31 02-03-2005 SCH 10545 10765 TUBING CUT RECORD; NS31 02-06-2005 SCH 1 10550 10758 TUBING CUT RECORD; NS31 01-02-2005 SCH 10650 111 00 IBP SETTING RECORD; NS31 01-05-2005 SCH 10545 10765 TUBING CUT RECORD; -// 'I r 0~( ~í?bLt/~- Please Si9 nd Return one copy of this transmittal. Thank V0t' James H. Johnson Petrotechnical Data Center SCJ-\NNED JUN 1 1/ 2005 Attn: Esther Fueg MB4-6 Attn: Ken Lemley MB4-6 Attn: Howard Okland (AOGCC) Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Kristin Dirks (DNR) Attn: Doug Choromanski (MMS) Pctrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 19-6612 bp ) _{!~MJJ,O 2 - I )( ~(.-' {) (£:,0 ., iI~::k...'........ ..-.:~f. -.-- BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 10 January 2005 Jeff Walker Regional Supervisor, Field Operations Minerals Management Service Office of Field Operations 3801 Centerpoint Drive. Suite 500 Anchorage, AK 99503 Howard Okland Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 Dear Mr. Walker and Mr. Oakland Please find the following Reservoir Engineering Reports that were prepared for BP enclosed: Slim Tube Study Northstar NS-31 (Westport 2002) - Paper and Digital Copy Minimum Miscibility Study for NS-06 (CoreLab 2003) - Paper and Digital Copy BP Alaska Northstar PVT and Miscibility studies - Final Report (Schlumberger) - Digital Copy The paper copies and CD have been marked "CONFIDENTIAL". BP requests that you hold these reports and data on the CD confidential pursuant to 11 AAC 82.810(a) and 38.05.035(a)(9)(C). Regards, ~~")~~ ACT East Subsurface Team BP Exploration (Alaska) Inc. (907) 564-5049 work SCANNED MAR 0 4 2.005 ) ~ O(l)/- II c; 0 Date: 1.1-11-2004 ~ tOO:<" ~¡~ TransmIttal Number: #91588 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Centerat (907) 564-4091 or by e-mailingtojohnsojh@bp.com Top SW Name Date Contractor Log Run Depth NS21 06-01-2004 SCH 1 0 (NS31 1,t) ( - 0"0 NS31 09-26-2004 PDS Bottom Depth Log Type 22244 PDC JEWELRY LOG; GAMMA RAY; CASING COLLAR LOG; LDWG EDIT OF JEWELRY PDC GAMMA RAY; CD ROM; 10776 LEAK DETECTION LOG; ~o 2.. "1(1 0 08-19-2004 PDS 1 0 10752 FLUID LEVEL X-Y CALIPER; cÆ" . ~ .V~ ,Â-OGe.C'.- Please Sign and¿~n one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Esther Fueg MB3-6 Attn: Ken Lemley MB3-6 Attn: Howard Okland (AOGCC) Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Kristin Dirks (DNR) Attn: Doug Choromanski (MMS) F~ "(:~. '1 \~r{" . NOV 1 ~;~ 2004 /\1~. L~..' r!:~ . ~:" ~ , ~" . 4 ~ ~.'.; . i.~ t I e. .) n \ì ç, ----~, ' 1 '\ U L..UU~} SCANNt:u JAN 0 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 @~ fE\ ~-e ~ rE fE\ n fE\ @ rw fE\ / @ L Lro - 11 'JJ lr Lro l1 Lro @ U~ w / FRANK H. MURKOWSKI, GOVERNOR AT ASKA OIL AND GAS 333 W. ]THAVENUE, SUITE 100 CONSERVATION COMMISSION / ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 J,OI-DfdJ Re: NorthstarNS31 Sundry Number: 304-412 Dear Mr. Archey: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. (7~r9Æ~ ~~ Chairman ./ BY ORDER OF THE COMMISSION DATED this It> day of November, 2004 Encl. SCANNED NO\! 1 5 200q. STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL NO V 0 20 MC 25.280 "f ') V...I GÆ- Ii 1'0 (z..OOt /)7;5 Ii 1/6 /4- r:: ~\\IF ~,"""""'~ li1 ",,,,,,,,,, '- 2004 1. Type of Request: 0 Abandon III Repair Well / 0 Plug Perforations 0 Stimulate 0 Alter Casing III Pull Tubing 0 Perforate New Pool 0 Waiver 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 0 Other 0 Time Extension 4. Current Well Class: 5. Permit To Dr.ill Number 0 Development 0 Exploratory / 201-060 / 0 Stratigraphic 181 Service / 6. API Number: /' 50- 029-23009-00-00 99519-6612 9. Well Name and Number: 56' 8. Property Designation: 10. Field / Pool(s): ADL 312799 NS31 / Northstar Unit , , 'I , ,f:>R~$ENrVY'1;4lqQN[)ITION$UMMARX ' Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 11281 11356 11198 None length Size MD' BÚrst 11. Total Depth MD (ft): 11440 Caši'rlg Structural Conductor Surface Intermediate Production Liner 199' 20" 3192' 13-3/8" 10884' 9-5/8" 658' 7" 199' 3237' 199' 3234' 10927' 1077' 10781' - 11439' 10631' - 11280' Perforation Depth MD (ft): Perforation Depth TVD (ft): 11150' - 11304' 10994' - 11146' Packers and SSSV Type: 7" SABL-3 Packer 7" HRQ SSSV Nipple Tubing Size: 7",29# Tubing Grade: 13Cr Packers and SSSV MD (ft): 10730' 2037' Tubing MD (ft): 10785' 13. Well Class after proposed work: / 0 Exploratory 0 Development iii Service / 15. Well Status after proposed work: December 15, 2004 0 Oil 0 Gas 0 Plugged Date: 0 WAG 181 GINJ 10 WINJ 12. Attachments: 181 Description Summary of Proposal 0 Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Pat Archey Title Senior Drilling Engineer fs {lAv0 0 BOP Sketch Signature Phone 564-5803 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 0 Plug Integrity flsop Test ~ Mechanical Integrity Test 0 Location Clearance Other: T € S t BO e E +0 4- Goo f! ¡. All r T y-t-t W't--( d. SCANNED NO\ll 5 200Ll 04. Junk (measured): None Cöllapse 4260 4930 2590 2270 7930 8160 6620 7020 0 Abandoned 0 WDSPL Contact Dan Kara, 564-5667 Datell/ðe/pl( Prepared By Name/Number: Sondra Stewman, 564-4750 I Sundry Number: 3D4-- '-tly ReDMS BFL NOV 1 2 2D04 ReDMS BFL NOV Y .< 7(!r1& COMMISSIONER APPROVED BY THE COMMISSION Date 11.~/f)IJ s~~~ D~PIZ.te ORIGINAL ) ) bp ... ,\I,.,,,, -.......~ ~...- ~..- --:....- 4.~ ~...... .'I'+lI\~ ". BP Exploration Alaska Inc. To: Winton Aubert - AOGCC Date: November 4, 2004 From: Dan Kara Northstar Drilling Engineer Subject: NS31 Application for Sundry Permit - Rig Workover (Replace /' Tubing) API #50-029-23009-00 Reference: Sundry approval is requested to replace the leaking 7" tubing on Northstar gas injection well NS31. Pre- workover preparation operations are expected to begin by mid December, 2004; rig operations to begin ".-' by mid January, 2005. Below is an outline of the current status of the well and proposed workover operations. NS31 SUMMARY OPERATIONS NS31 was completed in May, 2001 with 7" 29# 13Cr NSCC tubing. Gas injection commenced late 2001 and the well experienced pressure communication between the tubing and annulus shortly afterwards. A waiver to continue injection was granted by the AOGCC (attached). Production logging has determined the leak point to be at the production packer anchor(The purpose of the workover will be to replace the existing 7" tubing with new 7" 32# T -95 Vam Top HC tubing and a new production packer. The well is currently shut in with a tubing tail plug installed. ./ Proposed Pre-Rie: Operations: (mav be done with the rie:) 1. Fluid pack tubing and liner with seawater. " 2. Rig up slickline unit and pull the wireline retrievable SSSV. / 3. E-line set an inflatable bridge plug inside the 7" liner to isolate/protect live perfs. 4. RIH and dump bail sand or CaC03 plug above 7" inflatable. 5. RIH and chemical cut the first tubing joint above the packer. ,// 6. Circulate the well to seawater and freeze protect. 7. Remove wellhouse and flowlines. SCANNED! NO\i 1 5 2004 ) ) Proposed Rig Operations: 1. MIRU Nabors 33E. /' 2. Circulate the well to kill weight KCL brine (9.3 ppg). 3. Nipple down tree. Nipple up and test BOPE to 4800 psi. / 4. Pull the 7" tubing string. 5. Change out 9-5/8" packoff, if necessary, and test to 6500 psi. / 6. Rig up slickline. RIH with gauge ring / impression block to tubing stub. Rig down slickline 7. RIH with 5-1/2" tubing tail stinger and 7" 32# T-95 Vam Top HC tubing. 8. Land tubing hanger and test to 6500 psi. /~ 9. Rig up slickline and make drift run through the tubing tail. 10. Circulate well over to clean inhibited seawater and diesel (freeze protect). /' 11. Drop ball/rod and set packer. Test tubing to 5800 psi for 30 minutes. Test annulus to 5800 psi for 30 minutes. / 12. Set two-way check valve. Nipple down BOPE. Nipple up Tree and test to 6500 psi. 13. Pull two-way check valve. Set BPV. / 14. RDMO Nabors 33E. Post- Rig Work: 1. Pull ball/rod with slickline. Pull RHC ball seat with slickline. 2. Remove fill from ffiP. 3. Pull the 7" inflatable bridge plug. SCANNED NO\; 1 5 200L t ) ) :.;"r r? 1 t J L ¡i¡ r . "" f n ì ~ 'i . . 1\ \ t.,: } rO\:1 r-' ¡ß\ I ir~\ ,'''\.' ( I ~-. , L! .1 1_0- FRANK H. MURKOWSKI, GOVERNOR J\LltSIiA. OIL AND GAS CONSERVATION CO.MMISSION 333 W. ¡nt AVENUE, SUITE 100 ANCHORAGE, AlASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 July 15, 2004 RECEIVED Mr. Tom Gray Northstar Delivery Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99519-6612 Ii n ':1 í1 2. n ¡') It' .' \..,.:.- r.... ~I vU RE: Well Northstar 31 ("NS 31") gas injection waiver request. Dear Mr. Gray: The Alaska Oil and Gas Conservation Commission hereby approves the subject request by BP Exploration (Alaska) Inc. ("BPXA") and authorizes gas injection in NS 31 until June 30, 2005. Please be advised, however, that the Commission will not approve further time extensions of this waiver. . By letter dated April 28, 2003 the Commission requested that BPXA take action to cor- rect annular pressure communication in gas injection wells NS 27, NS 29, and NS 31. The Commission further stipulated that, absent corrective action taken on these wells, BPXA should suspend gas injection therein and secure the wells. BPXA subsequently replaced the tubing in NS 27 and NS 29 during the fourth quarter of 2003. On June 16, 2003 the Commission approved BPXA's request to continue gas injection in NS 31 until June 30, 2004. The Commission believes that the indefinite continuation of operation of NS 31 with documented annulus pressure communication creates significant and unnecessary well control risks. Accordingly, this waiver extension through June 30, 2005, is conditioned on BPXA's timely submission, for Commission approval, of a plan (using Fonn 10-403) to correct annular pressure communication in NS 31. This plan must be submitted to the Commission no later than December 1, 2004, and must provide for corrective action to be completed no later than June 30, 2005. In the absence of the timely submission of a plan for corrective action, BXP A will be required to suspend gas injection in NS 31 and secure the well. 1 (/' 1 . ~;)t\i£~äñ~~ Dan T. Seamount, Com~issioner SCANNEn NO\.! 1 5 20Df. TREE: ABB-VGI 7" 6.5 ksi WÉLLHEAD:ABB-VGI 13-5/8" 6.5 ksi Multibowl ") NS31 )so ELEV = 56' KB-BF. ELEV = 40.6' BASE FLANGE ELEV = 15.4' HRQ SSSV @2037' MD 2034' TVD 7" HRQ SVLN 5.963" ID 13 3/8", 68#/ft, L-80, BTC @3237' ..41 ~ 6.8PPG DIESEL FREEZE PROTECTION AT +1- 2700 r, 29/1/ft, 13cr,~) TUBING ID: 6.~ CAPACITY: 0.037 BBLlFT SAFETY NOTES: /' SLOW TUBING x IA COMM Operating Pressure of the 9 5/8" Annulus MUST NOT Exceed 3000 psi (11-21-02 Waiver) 7" R NIPPLE, @10709' 5.963" ID (OTIS) 7" R NIPPLE, @ 10755' 5.963" ID (OTIS) 7" RN NIPPLE, @10767' 5.77" ID (OTIS) 7" WLEG, @10785' 6.184" ID (OTIS)- -B~ ~ Baker SABL-3 PACKER ;L- . 6.00" 10 @10730' MO 10579' TVO B 7" LINER TOP @10781' MD 10629' TVD 6.184" ID J 95/8", 53.5#/ft L-80, BTC-M @10927' .. .... FERm\l(N9..M.M{ ÆFLOO ŒAIT(522I01) [T&h I..q; <H<IlASI] PN3..EA~ Níe Ria-to Ra1db1 œfa I'istot:a ¡:sf Œia Htiá Rrl- Qa-ga: 46J5Rwa-Jei, oM<; RrØréiicn 54"; HE .42~ Fhase: 72~ S2E s:F NllR'ÞLM) NlER/ÞL 1\,1) ~ D\lE 4.5 5 1118f -11Df 11CŒ-11144 Q:n 7/w.m1 4.5 5 111ffJ-1117U 1Gm-11012 Q:n 111192D1 SCANNED NO\I '1. 5 2004 IJ PBTD @11356' MD 11195' TVD TD @11439' ~ 7",29#,13Cr DATE 6/4/01 7/24/01 9/10/01 ~ REV. BY AGK ~Mt- EMF EMF t::Mt- COMMENTS Initial DiaQram Add Perf Inserted TVD Depths Add perf Updated KI:3 & ~afetv Info North~t#lr w-=. . : NS31 API Nn:50-O~9-~3009-00 BP Exploration (Alaska) r ~ TREE: ABB-VGI 7" 6.5 ksi WELLHEAD:ABB-VGI 13-5/8" 6.5 ksi Multibowl 133/8", 68#/ft, L-80, BTC @3237' 7", 32#/ft, T-95, VamTop .-/ TUBING 10: 6.094" ../ 7" R NIPPLE, -10600' 5.875" 10 (OTIS) 7" R NIPPLE, -10650' 5.875" 10 (OTIS) 7" RN NIPPLE, -10660' 5.75" 10 (OTIS) 7" R NIPPLE, @ 10709' & 10755': 5.963" 10 (OTIS 7" RN NIPPLE, @10767' 5.77" 10 (OTIS) 7" WLEG, @10785' 6.184" 10 (OTIS)- 9 5/8", 53.5#/ft L-80, BTC-M @10927' " ) Proposed NS31 Completion .4 ! B- .. FElTm\lI:Ns.AM'>R( RFLœ <RNr(5'2Ã01) [T&hl1:g: Œ<IlJlS1] AN3..EATTCPFHf: N:Je: Rfa" 1oFh:x1dKn [Bfa t-isII:Ji:a fØf d:œ ~ Fèf - Ü"a'g:[ 4!mR:wa-J:t, I-M<; R:rSraicn 51'; H:Je: .42'; Ræe: 72dg SZE s::F NIIßIÞLW NIIßIÞL l\¡1) Qn'S::¡z D\1E 4.5 5 11184'-1mf 1'Km-11144 Q:n 7/w.m1 4.5 5 11100-11170 'KmZ-11012 Q:n 1V192D1 PBTD @11356' MD 11195' TVD TO @11439' DATE 6/4/01 7/24/01 9/10/01 11/'l0/g1 1?T?77 ? REV. BY AGK I::MI- EMF EMF t::MI- COMMENTS Initial DiaQram Add Perf Inserted TVD Depths Add fJerf Updated KI:i & Safety Info [J j ~ )s. ELEV = 56' KB-BF. ELEV = 40.6' BASE FLANGE ELEV = 15.4' 7" R Nipple 32# @ -2000' MD/TVD .,,/ .. 6.8PPG DIESEL FREEZE PROTECTION AT +1- 2700 Baker S-3 Packer -10625' MD 5.5" 17# Tubing Tail Stinger to -10690' Chemical cut -10680' MD Baker SABL-3 PACKER 6.00" 10 @10730' MD 10579' TVD 7" LINER TOP @10781' MD 10629' TVD 6.184" 10 7", 29#, 13Cr North~t~r WFJ . : NS31 API NO:50-O?9.?3009-00 BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS r'-- ~ 1. Operations Performed: RepairWellD PluQ PerforationsD Stimulate 00 OtherD Abandon 0 Alter CasingD Pull TubingD Perforate New Pool 0 WaiverD Time ExtensionD Change Approved Program 0 Operation ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryD 201-0600 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceŒl 50-029-23009-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56.00 NS31 8. Property Designation: 10. Field/Pool(s): ADL-312799 Northstar Field / Northstar Oil Pool 11. Present Well Condition Summary: Total Depth measured 11440 feet true vertical 11280.8 feet Plugs (measured) None Effective Depth measured 11356 feet Junk (measured) None true vertical 11197.7 feet Casing Length Size MD TVD Burst Collapse Liner 671 7" 29# 13Cr80 10768 - 11439 10618.2 - 11279.8 8160 7020 Production 10884 9-5/8" 53.5# L-80 43 - 10927 43.0 - 10774.5 7930 6620 Surface 3192 13-3/8" 68# L-80 45 - 3237 45.0 - 3233.6 4930 2270 Perforation decth: Measured depth: 11150 -11170,11184 -11204,11204 -11244,11244 -11284,11284 -11304 True vertical depth: 10994.2 -11013.94,11027.75 -11047.49,11047.49 -11086.98,11086.98 -11126.48,11126.48 -11146.24 Tubing ( size, grade, and measured depth): 7" 29# Lo80 @ 44 - 10785 RECEIVED Packers & SSSV (type & measured depth): 7" Baker SABL-3 Packer @ 10730 SEP 1 6 2004 7" HES HRQ SSV @ 2037 7" Liner Top Packer @ 10781 1"-.... r. .:0 "-n -. ... "'. 12. Stimulation or cement squeeze summary: AlaSIUI un ~ '"'uv - Intervals treated (measured): Anchorage Treatment descriptions including volumes used and final pressure: 13 Recresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure Tubing Pressure Prior to well operation: 0 -84.9 0 1588 5023 Subsequent to operation: 0 -41.2 0 1569 4214 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ Copies of Logs and Surveys run - 16. Well Status after proposed work: Daily Report of Well Operations. ! OilD GasD WAGD GINJŒ] WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact Garry Catron 304-324 Printed Name Garry Catron Title Production Technical Assistant Signature l1éiAAMI.. C~~ Phone 564-4657 Date 9/15/04 '" R8DMS Sf L SEP 1 6 'l.Ø Form 10-404 Revised 4/2004 ,--- ..-.. NS31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/21/04 ACID TREATMENT: PRESSURE IA TO 4000 PSI (MAINTAIN WI TRIPLEX). PUMP DOWN TUBING: 83 BBLS 12% DAD ACID (20% XYLENE), DISPLACE WI 900 BBLS FILTER SW (89 DEG), CHASED W/5 BBL NEAT METH. WELL LEFT SHUT IN FOR OPS TO POP (OPS TO MAINTAIN 4000 PSI ON IA - THEN BLEED). LDFN FLUIDS PUMPED BBLS 9 Diesel 83 12% DAD Acid (20% Xylene) 900 Sea Water 5 Neat Methonal 997 TOTAL Page 1 NS-31 (PTD #2010600) Notification of Increased IA Repressurization SubjeetrNI4il,,'.i".iïM.~~*Notification of Increased IA Rcpressurization From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngincer@BP.com> Date: Mon, 06 Scp 2004 20:48:08 -0800 To: "AOGCC - Jim Regg (E-mail)" <jim_regg@admin.state.ak.us>,"AOGCC - Winton Aubert (.E-mail)" <winton - aubert@admin.state.ak.us> CC: "Francis, Michael J" <Michael.Francis@BP.com>, '~SU, ADWWell Opera6ons Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "Engel, HarryR" <EngeIHR@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "Reeves, Donald F" <ReevesDf@BP.com>, "NSU, ADW Wel1lritegrity Engineer" <NSUADWWellIntegrit)'Engineer@BP;com>,"PBD, Nstar Lead . Tech" <PBUNstarLeadTech@B~:com>/'PBU,Nstar Operations Manager" <PBUNstarOperationsManager@BP~com>, "PBU, Nstar Ops Team Leader" <PBUNstarOpsTeamLeader@BP.com>;i?Anders, Joe L" .<anders22@BP.com> '( e.¡~ q ('llik Jim and Winton, To follow-up with the voice-mail left with Winton on 9/4/04, NS-31 (PTD 2010600) is exhibiting an increase in the rate of IA repressurization. An attempt to NFT the well on 9/5/04 showed an IA repressurization rate of 600 psi in 1 hour. A MITIA passed to 3000 psi on 9/6/04. Current wellhead pressures are 4000/2650/0+. Operations continue to monitor the wellhead pressures to ensure the IA pressure does not exceed the limit of 3000 psi as stated in the AOGCC Sundry #304-257. Plans are being evaluated to conduct a video log prior to securing the well and are scheduled to begin on 9/9/04. With your approval, the well will remain on injection until secured. It is recognized the need to ensure this work is completed as soon as resources are available. A summary of recent activity on NS-31: 08/20/04: MITrA Passed to 5840 psi, state witness Chuck 09/04/04: Left voicemail with Winton regarding increase repressurization 09/05/04: Bled IAP 2660 > 1780 psi, IAP rose 600 psi in 09/06/04: MITIA Passed to 3000 psi Sheve unable to witness rate of IA 1 hour - NFT not possible A wellbore schematic has been included for reference. «NS31.pdf» Please contact me if you have any questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: NS3] .pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 91712004 9:48 AM TREE: ABB-VGI 7" 6.5 ksi WELLHEAD:ABB-VGI 13-5/8" 6.5 ksi Multibowl 133/8", 68#/ft, L-80, BTC @3237' 7", 29#/ft, 13Cr, NSCC TUBING ID: 6.184" CAPACITY: 0.037 BBLIFT 7" R NIPPLE, @10709' 5,963" ID (OTIS) 7" R NIPPLE, @ 10755' 5.963" ID (OTIS) 7" RN NIPPLE, @10767' 5.77" ID (OTIS) 7" WLEG, @10785' 6.184" ID (OTIS) 95/8", 53.5#/ft L-80, BTC-M @10927' - PBTD @11356' MD 11195' TVD TD @11439' NS31 DATE REV. BY COMMENTS Initial Dia ram Add Perf Inserted TVD Depths e ae RKB. ELEV = 56' KB-BF. ELEV = 40.6' BASE FLANGE ELEV = 15.4' HRQ SSSV @2037' MD 2034' TVD 7" HRQ SVLN 5.963" ID 6.8PPG DIESEL FREEZE PROTECTION AT +1- 2700 SAFETY NOTES: SLOW TUBING x IA COMM Operating Pressure of the 9 5/8" Annulus MUST NOT Exceed 3000 psi (11-21-02 Waiver) Baker SABL-3 PACKER 6.00" ID @10730' MD 10579' TVD 7" LINER TOP @10781' MD 10629' TVD 6.184"ID 7", 29#, 13Cr Northstar WELL: NS31 API NO:50-029-23009-00 BP Exploration (Alaska) [Fwd: NS31 IA Pressure 08-10-04.ppt] Subject: [Fwd: NS3] IA Pressure 08-1 0-04.ppt] From: Winton Aubert <winton_aubert@admin.state.ak.us> Date: Tue, 10 Aug 2004 ] 3:52:39 -0800 To: James B Regg <jimJegg@admin.state.ak.us> FYI. -------- Original Message -------- Subject: NS31 IA Pressure 08-10-04.ppt Date: Tue, 10 Aug 2004 13:45:54 -0800 From: Francis, Michael J <Michael.Francis@BP.com> To: Winton Aubert (E-mailT--~-winton-aubert@"admIn-:state. ak. us> CC: NSU, ADW Well Integrity Engineer ~NSU~Q~~~;lIntegrityE~g~~e~@B~.com>, Engel, Harry R <EngelHR@BP.com>, Denis, John R (ANC) <denisj@BP.com>, Garing, John D .~~~~~g~Q~BP.com> «NS31 IA Pressure 08-10-04.ppt» Winton, As per our discussion, a sundry to perform a Seal-Tite job in NS31 is on the way. We hope to start this work Sunday, August 15. I told you in our conversation that the NS31 IA pressure build rate seems to be going down over time. The attached PowerPoint slide shows this. Please call me if you have any questions or comments. Thanks, Mike IA Pressure Content-Type: application/vnd.ms-powerpoint Content-Encoding: base64 1 of 1 9/7/2004 10:09 AM - C") tn Z 0 0 ('I') LO t-- C\J 0 LO C\J LO C\J C\J ~ Q) ... ::J "§ Q) a. E Q) l- e: 0 :;::> u Q) "2' ¡r-- c:- ~~~ ~~...:~ 0 Q. LL () en :2: :2: Q) iií a::: e: 0 :;::> u Q) "2' ¡: ,. ~ ...;;.. "'l F r- ~ ~ en (1 u:: "0 Q) Q) ã5 I-=-- ~ \ I:-. ~ ~. . þ;:. . l ~ Q) ... ::J II) II) Q) ð: e: 0 :;::> u Q) '2' - ~ Q) ... ::J II) II) ~ Q. ~ I < ....... -r ~ ~ ~g ~ 9Jn¡eJ9dw9.l pUB 9¡e~ UO!¡:>9ful 0 0 C\J LO t-- ..- 0 LO ..- LO C\J ..- 0 0 ..- LO t-- 0 LO LO C\J 0 vOOl/O£/ L vOOl/6l/9 vOOl/O£/9 vOOl/O£/v vOOl/O£/£ vOOl/6l/l vOOl/6l/~ £OOl/O£/l ~ £OOl/O£/~ ~ £OOl/O£/O ~ £OOl/O£/6 £OOl/O£/9 £OOlH£/L £OOlH/L 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 LO 0 1.0 0 LO 0 LO 0 1.0 0 LO CO LO 1.0 -.:t -.:t ('I') ('I') C\I C\I ..- ..- 9JnSS9Jd I I en co ..c: Q) +-I co L.. ;:Iii ""'!tr .. ... ,.- t ~- -- ... --~ ~~ ~ -C Q) ~ .S ~ ..c +-I ~ Ci5 :::J > en 0 en-cT .: Q) Q) c. ~ ~a « 0 "" - Ci5 II '\ ,ti 1-.. w ~~ ...... IIIIIIIII ~ '\. ::::::::::iI ..... -~ .!III 411¡.,. .. '" """- ~ ~ ~ 'E' ~s ~ MIT form for NS-31 Subject: MIT fonn for NS-31 From: "NSU, ADW Well Integrity Engineer" <NSUADWWeHIntegrityEngincer@BP.com> Date: Fri, 20 Aug 2004 15 :40:59 -0800 To: 'winton:, "è~iD.st~t~;ák'.' ""'::!b~fI~emstem.@a~~statêli' jim.:..í-t,gg',,': .:sta~K~\îê>Us 'i'::'::,: ':~,¡:,,:je:::": :'{:'~'r; ,',",'¡~\. ,J;;':,~, '../:i CC: "Frand;",,' "ichael J',í <Miç~ael.Frai\~,s@B~;cOm>:/~NóréiÍe~;;Tylei: p-rt>:ti- 1D I - 0100 J~ ~/?4104- :,' . ¡>; :', :::':~:!',;: ,'i:'¡"':i~.: .N :"""""TM' ~np""':"'" oreIÏe .~. . Winton, Bob & Jim, Please find the MIT form for NS-31 attached. «MIT NS NS-31 08-20-04.xls» Jeff Jones mentioned something about needing a plot of the actual test data. I have enclosed a SCADA graph for referance and the actual digital data can be provided if you need. «Northstar 31 MITIA Graph.ZIP» Thanks, Donald Reeves - Filling in for JOE ANDERS Well Integrity Engineer 907-659-5102 907-659-5100 #1154 pgr NS NS-31 Content-Description: MIT NS NS-31 08-20-04.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 .............................. --'-""-----:,"""""""""""""""""""""""""'-""""""""""'-""""""'"""""..__m.... .. ..m.................. ....--........ ¡Content-Description: Northstar 31 MITIA Graph.ZIP '. Northstar 31 MITIA Graph.ZIP! Content-Type: application/x-zip-compressed I Content-Encoding: base64 I 1 of 1 8/24/2004 9:28 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin,state,ak,us; BobJleckenstein@admin,state,ak,us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc, Northstar / NS / NS 08/20/04 Tyler Norene 0 P ¡./' Well P,T.D. Notes: Well P.T.D, Notes: Well P,T.D, Notes: Well P.T.D, Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 2004-0820_MIT _Northstar_NS-31 ,xis Northstar 31 MITIA Graph 08/20/2004 NS31 I-IA Pressure - Tubing Pressure I 6000 5900 5800 5700 5600 5500 5400 5300 5200 5100 5000 4900 4800 e 4700 ;¡ 4600 :I 4500 à: 4400 ~ 4300 4200 4100 4000 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 0 9. ' --- I' II 0 0 N ...... ...... ...... v Q 0 ~ v 0 ð ~ co 4200 4180 4160 4140 4120 4100 4080 4060 4040 4020 4000 3980 3960 e 3940 ;¡ 3920 :I 3900 à: 3880 ~ 3860 :c 3840 .= 3820 3800 3780 3760 3740 3720 3700 3680 3660 3640 3620 3600 0 0 M ...... v Q 0 ~ co ~ ~ ~V~VŒ [ffi~ ~~~~æ~ / AlfASIiA OIL AlQ) GAS / CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 dvO { -oC2 Q August 20,2004 Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-661 Re: Northstar NS#31 304-324 Dear Mr. Francis: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Enclosure bp ",--. , ~ "t.,. ..~~ ~~. .':~ ~:'. ."'~~\\. ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 August 13,2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS31 to Acidize/Water Wash (Ivishak) BP Exploration Alaska, Inc. proposes to acidize and water wash the NS31 well. NS31 injectivity has declined. The acid is designed to attack any solids (pipe / scale, hydrogen sulphide, etc.) that may have accumulated in the perforation tunnels. The water should attack any salt that has accumulated since injection start-up. The procedure includes the following major steps: . Bullhead HCI based acid treatment and displace with water. / . Return well to gas injection Sincerely, ~~ t1~fr ~ Senior Petr um Engineer BPXA, ACT, Northstar RECEIVED AUG 17 2004 Alaska Oil & Gas Cons. Commission Anchorage ORJG'~JAL .r-.. 1JJC:l fit- ~ (lq I z..o°4- STATE OF ALASKA ÐßS 8'/ I' fR ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED - APPLICATION FOR SUNDRY APPROVA~UG 17'2004 20 AAC 25.280 StratigraphicD Service ŒJ / 9. Well Name and Number: NS31 ,,/ 10. Field/Pool(s): Northstar Field 1 Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11356 11141.7 MD TVD ,~ 1. Type of Request: Abandon D Alter Casing D Change Approved Program 0 2. Operator Name: Suspend D Repair Well D Pull Tubing 0 BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.00 KB 8. Property Designation: ADL-312799 11. Total Depth MD (ft): 11440 Casing Total Depth TVD (ft): 11280.8 Length Liner 671 Production 10884 Surlace 3192 Perforation Depth MD (ft): 11150 - 11170 11184 - 11204 11204 - 11244 11244 - 11284 11284 11304 Packers and SSSV Type: 7" Baker SABL-3 Packer 7" HES HRQ SSV 7" Liner Top Packer 12. Attachments: Description Summary of Proposal Œ 7" 29# 13Cr80 9-5/8" 53.5# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 10994.2 11013.9 11027.8 11047.5 11047.5 11087.0 11087 11126.5 11126.5 11146.2 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencin 0 eration: 16. Verbal Approval: Commission Representative: August 30, 2004 Date: Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Alaska I as on. PerforateD waivA~orto@ular DisposalD StimulateŒ Time ExtensionD OtherD Re-enter Suspended Well 0 5. Permit to Drill Number: 201-0600 ,,/ Development 0 Exploratory 0 6. API Number 50-o29-23OO9-o0-o0 Plugs (md): None Burst Junk (md): None Collapse to bottom to bottom 10768 11439 10618.2 11279.8 8160 7020 43 10927 43.0 10774.5 7930 6620 45 3237 45.0 3233.6 4930 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 7" 29 # L-80 44 10785 Packers and SSSV MD (ft): 10730 2037 10781 13. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ 15. Well Status after proposed work: Oil 0 GasO /IUggedO AbandonedO WAG D GINJŒ WINJ WDSPLD Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Contact Michael Francis .t;:... Title Phone 8/16/04 Petroleum Engineer 564-4240 ommlsslon Use nl Sundry Number: .30 BOP TestO Conditions of approval: Notify Commission so that a representative may witness Mechanciallntegrity Test D Location Clearance 0 Other: - 404- Form 10-403 Revised 06/2004 RIllS 8Ft AUG 2 3 2an~ BY ORDER OF THE COMMISSION Date: ORIGINAL SUBMIT IN DUPLICATE TREE: ABB-VGI 7" 6.5 ksi WELLHEAD:ABB-VGI 13-5/8" 6.5 ksi Multibowl N531 133/8", 68#/ft, L-80, BTC @3237' 7", 29#/ft, 13Cr, NSCC TUBING ID: 6.184" CAPACITY: 0.037 BBUFT 7" R NIPPLE, @10709' 5.963" ID (OTIS) 7" R NIPPLE, @ 10755' 5.963" ID (OTIS) 7" RN NIPPLE, @10767' 5.77" ID (OTIS) 7" WLEG, @10785' 6.184" ID (OTIS) 95/8", 53.5#/ft L-80, BTC-M @10927' - PBTD @11356' MD 11195' TVD TD @11439' DATE REV. BY COMMENTS ~KB. ELEV = 56' KB-BF. ELEV = 40.6' BASE FLANGE ELEV = 15.4' HRQ SSSV @2037' MD 2034' TVD 7" HRQ SVLN 5.963" ID 6.8PPG DIESEL FREEZE PROTECTION AT +1- 2700 SAFETY NOTES: SLOW TUBING x IA COMM Operating Pressure of the 9 5/8" Annulus MUST NOT Exceed 3000 psi (11-21-02 Waiver) Baker SABL-3 PACKER 6.00" ID @10730' MD 10579' TVD 7" LINER TOP @10781' MD 10629' TVD 6.184" ID 7",29#,13Cr Northstar WELL: NS31 API NO:50-029-23009-00 BP Exploration (Alaska) bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 10, 2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501 Dear Winton: ~eJ~ Re: Sundry Notice for NS31 Seal-Tite leak Repair BP Exploration Alaska, Inc. proposes to use Seal-Tite sealant to repair a very minor leak between the 7" tubing and 9-5/8" casing. The location of this leak has never been identified, but offset wells NS27 and NS29 had packer seal leaks. This procedure will attempt to place Seal- Tite sealant in the packer seal. The procedure includes the following major steps: . Set a plug in the tubing tail . Dump-bail Seal- Tite sealant across the packer . Pressure up on the tubing and bleed down the IA pressure . Retrieve tubing tail plug SCANNEr: AUG 2, '7 200f: Sincerely, ~ 'J~ ~.~~ Mi ael J. nCIS, P.E. Senior Petroleum Engineer BPXA, ACT, Northstar r' ,"- I-, : 0 ) . ~..~ j'1jt~r,~ r'(~ri. A\lJS 2,0 .' ORIGINAL W 6. It- , ( f( ( t,(/(/ 'T STATE OF ALASKA D~ ,pIlI /6/ ALASKA OIL AND GAS CONSERVATION COMMISSION -v-- APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Stratigraphic D Service Œ] 9. Well Name and Number: NS31 10. FieldlPoôl(s): Northstar Field 1 Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11356 11141.7 MD TVD 1. Type of Request: Abandon 0 Alter Casing D Change Approved Program 0 2. Operator Name: Suspend 0 RepairWell 00 Pull Tubing 0 BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.00 KB 8. Property Designation: ADL-312799 11. Total Depth MD (ft): 11440 Casing Total Depth TVD (ft): 11280.8 Length Liner 671 Production 10884 Surlace 3192 Perforation Depth MD (ft): 11150 - 11170 11184 - 11204 11204 - 11244 11244 - 11284 11284 - 11304 Packers and SSSV Type: 7" Baker SABL.3 Packer 7" HES HRQ SSV 7" Liner Top Packer 12. Attachments: Description Summary of Proposal D 7" 29# 13Cr80 9-5/8" 53.5# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 10994.2 11013.9 11027.8 11047.5 11047.5 11087.0 11087 11126.5 11126.5 11146.2 Detailed Operations Program 00 BOP Sketch D 14. Estimated Date for Commencin 0 eration: 16. Verbal Approval: Commission Representative: August 15,2004 Date: Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: PerforateD WaiverO Annular DisposalD StimulateD Time ExtensionD OtherD Re-enter Suspended Well 0 5. Permit to Drill Number: 201-0600 Development D Exploratory D 6. API Number 50-029-23009-00-00 Plugs (md): None Burst Junk (md): None Collapse to bottom to bottom 10768 11439 10618.2 11279.8 8160 7020 43 10927 43.0 10774.5 7930 6620 45 3237 45.0 3233.6 4930 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 7" 29 # L-80 44 10785 Packers and SSSV MD (ft): I 0 ?(104 15. Well Status after proposed work: Oil D GasO PluggedO AbandonedO WAG D GINJI!] WINJD WDSPLD Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Contact Michael Francis Title Phone Petroleum Engineer 564-4240 8/10/04 Conditions of approval: Notify Commission so that a representative may witness BOP TestO Mechanciallntegrity Test ø' Other: Subseque - 404- Location Clearance 0 fIØI& Bf L. MlG 2 0 1004 BY ORDER OF THE COMMISSION Date: Form 10-403 Revised 06/2004 ORIGINAL SUBMIT IN DUPLICATE TREE: ABB-VGI 7" 6.5 ksi WELLHEAD:ABB-VGI 13-5/8" 6.5 ksi Multibowl 13 3/8", 68#/ft, L-80, BTC @3237' 7", 29#/ft, 13Cr, NSCC TUBING ID: 6.184" CAPACITY: 0.037 BBUFT 7" R NIPPLE, @10709' 5.963" ID (OTIS) 7" R NIPPLE, @ 10755' 5.963" ID (OTIS) 7" RN NIPPLE, @10767' 5.77" ID (OTIS) 7" WLEG, @10785' 6.184" ID (OTIS) 95/8", 53.5#/ft L-80, BTC-M @10927' - PBTD @11356' MD 11195' TVD TD @11439' NS31 DATE COMMENTS Initial Dia ram Add Perf Inserted TVD Depths e ae REV. BY RKB. ELEV = 56' KB-BF. ELEV = 40.6' BASE FLANGE ELEV = 15.4' HRQ SSSV @2037' MD 2034' TVD 7" HRQ SVLN 5.963" ID 6.8PPG DIESEL FREEZE PROTECTION AT +1- 2700 SAFETY NOTES: SLOW TUBING x IA COMM Operating Pressure of the 9 5/8" Annulus MUST NOT Exceed 3000 psi (11-21-02 Waiver) Baker SABL-3 PACKER 6.00" ID @10730' MD 10579' TVD 7" LINER TOP @10781' MD 10629' TVD 6.184" ID 7",29#, 13Cr Northstar WELL: NS31 API NO:50-029-23009-00 BP Exploration (Alaska) , (~~.. :-¡-f /I.\ "fr rT~' r ",' 'l ¡ ; :.,', ¡ ~ ! t '. :_: I ~ L./ '._", u :. ,.:: -. 1"-- ( r:", I ~~ , . ' , ~- : I II ! --, \.~..,: ~j (ì~.\ f1 0\\ (!tJ r V:;.-r I):, \ !IJ' I! :L', ,....,\~\ ~ I I ' \ -, I I' '- I ¡--;, \ L_~' ~\ ", ! l. : I \ \ " ' , , L.. _.J - L, L . - - . " . - ., '., FRANK H. MURKOWSKI, GOVERNOR AI~A~1iA. OIL AlWD GAS CONSERVATION COMMISSION 333 W. r" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 July 15, 2004 Mr. Tom Gray Northstar Delivery Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99519-6612 dO 1- D 60 RE: Well Northstar 31 ("'NS 31") gas injection waiver request. Dear ,Mr. Gray: The Alaska Oil and Gas Conservation Commission hereby approves the subject request by BP Exploration (Alaska) Inc. C'BPXA") and authorizes gas injection in NS 31 until June 30, 2005. Please be advised, however, that the Comn1ission will not approve further time extensions of this waiver. By letter dated April 28, 2003 the Comn1ission requested that BPXA take action to cor- rect annular pressure communication in gas injection \\Tel1s NS 27, NS 29, and NS 3l. The Commission further stipulated that, absent corrective action taken on these wells, BPXA should suspend gas injection therein and secure the wells. BPXA subsequently replaced the tubing in NS 27 and NS 29 during the fourth quarter of 2003. On June 16, 2003 the Commission approved BPXA's request to continue gas injection in NS 31 until June 30, 2004. The Comn1Ïssion believes that the indefinite continuation of operation of NS 31 ,vith documented annulus pressure communication creates significant and unnecessary well control risks. Accordingly, this waiver extension through June 30, 2005, is conditioned on BPXA's timely submission, for COllll11ission approval, of a plan (using Fonn 10-403) to con-ect annular pressure communication in NS 31. This plan must be submitted to the Commission no later than December 1, 2004, and must provide for corrective action to be completed no later than June 30, 2005. In the absence of the timely submission of a plan for corrective action, BXP A wil1 be required to suspend gas injection in NS 31 and secure the well. ¥~ bp ,\t~ . .-...~~ ~.::- ..~ ~. 1'.'_'- BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 10,2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501 Dear Winton: ~eJ~ Re: Sundry Notice for NS31 Seal-Tite Leak Repair BP Exploration Alaska, Inc. proposes to use Seal-Tite sealant to repair a very minor leak between the 7" tubing and 9-5/8" casing. The location of this leak has never been identified, but offset wells NS27 and NS29 had packer seal leaks. This procedure will attempt to place Seal- Tite sealant in the packer seal. The procedure includes the following major steps: . Set a plug in the tubing tail . Dump-bail Seal- Tite sealant across the packer . Pressure up on the tubing and bleed down the IA pressure . Retrieve tubing tail plug Sincerely, ~ 'J~ èJvMl . J:1. ~ Mi ael J. nCIS, P.E. Senior Petroleum Engineer BPXA, ACT, Northstar ;. r: .¡ )1104 .~i~JIfW,.g ~"~ri. AiJ6 2,0 .' ORIGINAL V..J 6.1\- --'( ( f( ( ¿..(/U 't STATE OF ALASKA D/:!, Y/'/ I ðl ALASKA OIL AND GAS CONSERVATION COMMISSION -V- APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 StratigraphicD Service ŒJ 9. Well Name and Number: NS31 10. Field/Poõl(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11356 11141.7 MD TVD 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: Suspend 0 RepairWell 00 Pull Tubing 0 BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.00 KB 8. Property Designation: ADL-312799 11. Total Depth MD (ft): 11440 Casing Total Depth TVD (ft): 11280.8 Length Size Liner 671 Production 10884 Surlace 3192 Perforation Depth MD (ft): 11150 - 11170 11184 - 11204 11204 - 11244 11244 - 11284 11284 - 11304 Packers and SSSV Type: 7" Baker SABL-3 Packer 7" HES HRQ SSV 7" LIner Top Packer 12. Attachments: Description Summary of Proposal D 7" 29# 13CrSO 9-5/8" 53.5# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 10994.2 11013.9 11027.8 11047.5 11047.5 11087.0 11087 11126.5 11126.5 11146.2 Detailed Operations Program ŒI BOP Sketch D 14. Estimated Date for Commencin 0 eration: 16. Verbal Approval: Commission Representative: August 15,2004 Date: Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: PerforateD WaiverO StimulateD Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 201-0600 Annular Disposal D OtherD Development D Exploratory D 6. API Number 50-029-23009-00-00 Plugs (md): None Burst Junk (md): None Collapse to bottom to bottom 10768 11439 10618.2 11279.8 8160 7020 43 10927 43.0 10774.5 7930 6620 45 3237 45.0 3233.6 4930 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 7" 29 # L-80 44 10785 Packers and SSSV MD (ft): I 0 ?('O4 15. Well Status after proposed work: Oil D GasO PluggedO AbandonedO WAG D GINJŒ WINJD WDSPLD Prepared by GarIY Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Contact Michael Francis Title Phone Petroleum Engineer 564-4240 8/1 0/04 ommlsslon Use n Conditions of approval: Notify Commission so that a representative may witness BOP TestO Mechanciallntegrity Test æ(' Other: Subseque - 404- Location Clearance 0 rIØIIBFL AUG àt U 2004 BY ORDER OF THE COMMISSION Date: Form 10-403 Revised 06/2004 ORIGINAL SUBMIT IN DUPLICATE TREE: ABB-VGI 7" 6.5 ksi WELLHEAD:ABB-VGI 13-5/8" 6.5 ksi Multibowl NS31 13 3/8", 68#/ft, L-80, BTC @3237' 7", 29#/ft, 13Cr, NSCC TUBING ID: 6.184" CAPACITY: 0.037 BBUFT 7" R NIPPLE, @10709' 5.963" ID (OTIS) 7" R NIPPLE, @ 10755' 5.963" ID (OTIS) 7" RN NIPPLE, @10767' 5.77" ID (OTIS) 7" WLEG, @10785' 6.184" ID (OTIS) 95/8", 53.5#/ft L-80, BTC-M @10927' - PBTD @11356' MD 11195' TVD TD @11439' DATE 6/4/01 7/24/01 9/10/01 REV. BY COMMENTS RKB. ELEV = 56' KB-BF. ELEV = 40.6' BASE FLANGE ELEV = 15.4' HRQ SSSV @2037' MD 2034' TVD 7" HRQ SVLN 5.963" ID 6.8PPG DIESEL FREEZE PROTECTION AT +/- 2700 SAFETY NOTES: SLOW TUBING x IA COMM Operating Pressure of the 9 5/8" Annulus MUST NOT Exceed 3000 psi (11-21-02 Waiver) Baker SABL-3 PACKER 6.00" ID @10730' MD 10579' TVD 7" LINER TOP @10781' MD 10629' TVD 6.184" ID 7",29#,13Cr Northstar WELL: N531 API NO:50-029-23009-00 BP Exploration (Alaska) ~ 4,-t 81'~I¿l..lq. STATE OF ALASKA . 'T ~: ALASKA OIL AND GAS CONSERVATION COMMISSION,¡''',' '.,'"'' . ,I. APPLICATION FOR SUNDRY APPROV~~~t" 20 AAC 25.280 ,; . ,. )_l]ù4 1, Type of Request: Suspend 0 Repair Well 0 Pull Tubing D Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Abandon 0 Alter Casing 0 Change Approved Program D 2, Operator Name: BP Exploration (Alaska), Inc. Development D PerforateD WaiverŒJ Annular DisposalD StimulateD Time ExtensionD OtherD Re-enter Suspended wellD 5. Permit to Drill Number: 201-0600 ,/ Exploratory D 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7, KB Elevation (ft): 56.00 KB 8, Property Designation: ADL-312799 Length StratigraphicD Service ŒJ ,/ 9. Well Name and Number: N531 /' 10, Field/Pool(s): Northstar Field / Northstar Oil Pool ,," PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11356 11141,7 MD TVD 6, API Number / 50-029-23009-00-00 11, Total Depth MD (ft): 11440 Casing Total Depth TVD (ft): 11280,8 Size Plugs (md): None Burst Junk (md): None Collapse Conductor 153 Liner 671 Production 10884 Surface 3192 Perforation Depth MD (ft): 11150 - 11170 11184 - 11204 11204 - 11244 11244 - 11284 11284 - 11304 Packers and SSSV Type: 7" Baker SABL-3 Packer 7" HES HRQ SSV 7" Liner Top Packer 12, Attachments: Description Summary of Proposal ŒJ 20" 169# X-56 7" 29# 13Cr80 9-5/8" 53.5# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 10994 11013.9 11028 11047.5 11047 11087.0 11087 11126.5 11126 11146.2 top bottom top bottom 46 199 46.0 199.0 4260 2590 10768 11439 10618.2 11279.8 8160 7020 43 10927 43.0 10774.5 7930 6620 45 3237 45.0 3233.6 4930 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 7 " 29 # L-80 44 10785 Packers and SSSV MD (ft): 10730 2037 10781 13, Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 DevelopmentD Service ŒJ 14, Estimated Date for Commencing Operation: 16, Verbal Approval: Commission Representative: 17, I hereby certify that the foregoing is true and correct to the best of my knowledge, Date: 15, Well Status after proposed work: Oil D GasD WAG D GINJŒ] / Plugged D Abandoned D WINJD WDSPLD Prepared by Garry Catron 564-4657. July 1, 2004 Contact Anna Dube I Joe Anders Printed Name Signature Joe Anders, P .E. ) fit av. r;l pV1 Title Phone Well Integrity Coordinator 659-5102 6/30/04 Commission Use Only !fission so that a representative may witness Sundry Number: 30{-d.iï BOP TestD Mechanciallntegrity Test D Location Clearance D BY ORDER OF THE COMMISSION Date: 1/s lor "-- ORIGINAL SUBMIT IN DUPLICATE Form 1 0-403 Revised 12/2003 BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage. Alaska 99519-6612 O.~p I .": ,~ June 30, 2004 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. ih Ave. Anchorage, Alaska 99501 Subject: NS31 (PTD 2010600) Application for Cancellation of Sundry #303-162 Application for Sundry Approval for Gas Injection with Slow TxlA Communication Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 303-162 and Application for Sundry Approval form 10-403 for Northstar well 31 (PTD 2010600). Purpose of this request is to continue gas injection into NS31 with slow TxlA communication. Sundry 303-162 expires 6/30/04. If you require any additional information or clarification, please contact me or Anna Dube at (907) 659-5102. Sincerely, ; ~ av.dw7 I Joe Anders, P.E. Well Integrity Coordinator \.. :, " '" Attachments Report of Sundry Well Operations form 1 0-404 Application for Sundry Approval form 10-403 Description Summary of Proposal Wellbore Schematic TIO Plot H )' r-, .i:. L ~) " In U 4 nQ\G\~JAL NS31 Description Summary of Proposal 06/30/04 Problem: Gas Injector with Slow TxlA Communication Well History and Status Well NS31 (PTD 2010600) is a gas injector that exhibits slow TxlA communication exhibited in slow IA re-pressurization. Bleeds are occurring approximately once every 2 months to keep the IA pressure below 3000 psi. The IA pressure is observed to increase as much as 300 psi/day, depending on injection temperature and pressure. On 12/08/01, an MITIA passed to 2700 psi with the well on injection. Summary of recent events: > 06/01/01: Rig conducted MITIA Passed to 5500 psi > 12/08/01: AOGCC witnessed M ITIA Passed to 2700 psi > 01/02/03: NFT-IA Passed This sundry request is to allow for continued gas injection. The following supports the request: - An MITIA passed to 2700 psi on 12/08/01, demonstrating competent production casing. - The IA repressurization rate is low, averaging approximately 15 psi/day. Pressures, temperature and injection rate are monitored and recorded daily. - The production casing is rated to a burst pressure of 7930 psi, 44% greater than injection pressure. Proposed Action Plan 1. Allow well to continue gas injection. 2. Limit the IA operating pressure to 3000 psi. 3. Record wellhead pressures, temperature, and injection rates daily. Also record IA bleeds. 4. Submit a monthly report of daily pressures, temperatures, and injection rates. 5. Perform a MITIA once every 2 years. 6. Notify the AOGCC if the bleed rate increases significantly. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1, Operations Performed: Abandon D Alter CasingD Change Approved Program D 2, Operator Suspend D Repair WellD Pull TubingD Operation ShutdownD Plug PerforationsO Perforate New POOIO 4, Current Well Class: Perforate D WaiverD Stimulate 0 Time ExtensionD Re-enter Suspended WellD Other[!] Cancel Sundry Name: BP Exploration (Alaska), Inc. 5, Permit to Drill Number: 201-0600 Development 0 56.00 8. Property Designation: ADL-312799 11, Present Well Condition Summary: StratigraphicO 9. Well Name and Number: NS31 10, Field/Pool(s): Northstar Field / Northstar Oil Pool EXPloratoryD ServiceŒ] 6, API Number 50-029-23009-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 11440 feet true vertical 11280.8 feet Plugs (measured) None Effective Depth measured 11356 feet true vertical 11197.7 feet Junk (measured) None Casing Length Size MD TVD Burst Collapse Conductor 153 20" 169# X-56 46 199 46.0 199.0 4260 2590 Liner 671 7" 29# 13Cr80 10768 - 11439 10618.2 - 11279.8 8160 7020 Production 10884 9-5/8" 53.5# L-80 43 - 10927 43.0 - 10774.5 7930 6620 Surface 3192 13-3/8" 68# L-80 45 - 3237 45.0 - 3233.6 4930 2270 Perforation depth: Measured depth: 11150 -11170,11184 -11204,11204 -11244,11244 -11284,11284 -11304 True vertical depth: 10994.2 - 11013.94, 11027.75 - 11047.49, 11047.49 - 11086.98, 11086.98 - 11126.48, 11126.48 . 11146.24 Tubing ( size, grade, and measured depth): 7" 29# L-80 @ 44 10785 Packers & SSSV (type & measured depth): 7" Baker SABL-3 Packer 7" HES HRQ SSV 7" Liner Top Packer @ 10730 @ 2037 10781 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Oil-Bbl Representative Daily AveraQe Production or Injection Data Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14, Attachments: 15, Well Class after proposed work: ExploratoryD DevelopmentD Service ŒJ Signature Joe Anders/Anna Dube Joe Anders, P.E. }vI tL-Þ"" 16. Well Status arter proposed work: Operational Shutdown D Oil 0 GasD WAG 0 GINJŒ] WINJD WDSPLD Prepared by Garry Catron (907) 564-4657, Sundry Number or N/A if C,O, Exempt: 303-162 Copies of Logs and Surveys run - Daily Report of Well Operations - 17, I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact Printed Name Title Well Integrity Coordinator Phone 659-5102 Date 6/30/04 Form 10-404 Revised 12/2003 .. TREE: ABB-VGI 7" 6,5 ksi WELLHEAD:ABB-VGI 13-5/8" 6.5 ksi Multibowl NS31 , .KB. ELEV = 56' KB-BF. ELEV = 40,6' BASE FLANGE ELEV = 15,4' HRQ SSSV @2037' MD 2034' TVD 7" HRQ SVLN 5,963" ID 133/8", 68#/ft, L-80, BTC @3237' .4 .. 6.8PPG DIESEL FREEZE PROTECTION AT +/- 2700 7", 29#/ft, 13Cr, NSCC TUBING 10: 6.184" CAPACITY: 0.037 BBUFT SAFETY NOTES: SLOW TUBING x IA COMM Operating Pressure of the 9 5/8" Annulus MU~T NOT Exceed 3000 psi (11-21-02 Waiver) 7" R NIPPLE, @10709' 5,963" 10 (OTIS) ~ 7" R NIPPLE, @ 10755' 5.963" ID (OTIS) 7" RN NIPPLE, @10767' 5.77" ID (OTIS) 7" WLEG, @10785' ! 6,184" ID (OTIS)- 95/8", 53.5#/ft L-80. BTC-M @10927' ~ Baker SABL-3 PACKER ~L- 6.00"ID @10730' MD 10579' TVD B 7" LINER TOP @10781' MD 10629' TVD 6.184" I D .. FffiCffilOJ9.M,'PR( Æf Læ CRAIT (5ZM) [11e-h lctJ. CRCIlJL81] AN3..EAT1CFFIJf: N:1e: Rt a' to Rt:x:1.dicn æ fa Iisk:rica p:rl Œta hIia Rrl- Cta"ge: 4ffER>Na-.b, I-M<; Fè1eÐab1: Sf'; !-tie: ,42'; Rø;e: 72d:g S2E æ: NIffiJ.ALfl.D NIffiJ.AL lVD Qn'9:1z o:\lE 4,5 5 11181- 11~' 11(J;6-111.J4' QJ1 7/141:m1 4.5 5 11100-11170 1cæ2-11012 Q:11 1VI94X)1 Q PBTO @11356' MD 11195' TVD TO @11439' j\\~~':'~1"1;; '1~¡!.J,~\':*:';';v!'~;~ I\~'I'~'!~ :11' \"" : I'í .' ", ~(~.~' '.~' '¥ "11,' 1 , oIl.:¡.,, ..1 ", ~r'". ¡;ol 7", 29#, 13Cr DATE 6/4/01 7/24/01 9/1 % 1 1 ~~~9~8j REV. BY A<.;K i::Mt- EMF EMF i::MI- COMMENTS , Initial DiaQram Add Perf Inserted TVD Depths - Add fJerf Updated Ki:S & ~afetv Info Northstar WFJ J : NS31 API NO:50-0?9-?3009-00 BP Exploration (Alaska) -----"----"- -.--------- 6,000 - 5,000 4.000 QJ I.. :3 en 3.000 en (1) I.. 0. 2,000 1,000 0 7/1/2003 1---- 9/1/2003 NS-31 TIC Plot -, -------.-- ------- -- . Tbg ~- ~ ~~"" ,~. " ,...' ,:. ,. '.. ,t,.. '. ' ¡' .& ' .. .. ¡e"': .. : ~ .. , .'~ ... : . " ':1 " , . ,; I, , I ::; .1 . . IA I , : ¡ ¡ : ~ :¡ 1). :! !I.: 1::1 ~~ ~ .. il ¡'/ " \i. ! ¡ ".' 11M :: If " ¡; ,~,: ; / ' ':/ ¡", (,¡..' : ¡ i' . II t'~~l ' ¡ ¡ , !~~, '"",': 'i " .' ~'IffY,'_W I~C¡ ) d;,~~", I , ~"ll,:d. -rlJ, I' ~~ I ' r¡>;.:3"",w,r ~~~~,~~- 11/1/2003 1/1/2004 3/1/2004 5/1/2004 7/1/2004 . OA OOA I II OOOA I f ( ( BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 June 18, 2004 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. ih Ave. Anchorage, Alaska 99501 Subject: NS31 (PTD 2010600) Application for Cancellation of Sundry #303-162 Application for Sundry Approval for Gas Injection with Slow TxlA Communication Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 303-162 and Application for Sundry Approval form 10-403 for Northstar well 31 (PTD 2010600). Purpose of this request is to continue gas injection into NS31 with slow TxlA communication. Sundry 303-162 expires 6/30/04. If you require any additional information or clarification, please contact Anna Dube or Joe Anders at (907) 659-5102. ;;¡~ {hk Anna Dube Well Integrity Coordinator Attachments Report of Sundry Well Operations form 10-404 Application for Sundry Approval form 10-403 Description Summary of Proposal Wellbore Schematic TIO Plot RE ~\>E-rV' E'D . . C .,.J :.,... JUN 2 3 2004 A.laska on 8t ( ,( STATE OF ALASKA ( ALASKA Oil AND GAS CONSERVATION COMMISSION 1. Operations Performed: REPORT OF SUNDRY WELL OPERATIR~~ClVr Abandon 0 SuspendD Operation ShutdownD Perforate 0 Öaiver~ Other[!] Alter CasingO Repair Well 0 Plug PerforationsO Stimulate 0 Time ~tJn~io~[j1 ?nnå Change Approved ProgramO Pull TubingO Perforate New PoolO Re-entß,ri:s.-û$P~Dde.çI WellO Cal1cel SU,nøry 2. Operator 4. Current Well Class: 5. Permitto'Drill,Number: Name: BP Exploration (Alaska), Inc. 201-0600 Development 0 ExploratoryO 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.00 8. Property Designation: ADL-312799 11. Present Well Condition Summary: StratigraphicO 9. Well Name and Number: NS31 10. Field/Pool(s): Northstar Field / Northstar Oil Pool ServiceŒ) 6. API Number 50-029-23009-00-00 Total Depth measured 11440 feet true vertical 11280.8 feet Plugs (measured) Junk (measured) None Effective Depth measured 11356 feet true vertical 11197.7 feet None Casing Conductor Liner Production Surface Length 153 671 10884 3192 Size 20" 169# X-56 7" 29# 13Cr80 9-5/8" 53.5# L-80 13-3/8" 68# L-80 MD TVD 46 - 199 46.0 - 199.0 10768 - 11439 10618.2 - 11279.8 43 - 10927 43.0 - 10774.5 45 - 3237 45.0 - 3233.6 Burst Collapse 2590 7020 6620 2270 4260 8160 7930 4930 Perforation depth: Measured depth: 11150 -11170, 11184 -11204,11204 -11244,11244 -11284, 11284 -11304 True vertical depth: 10994.2 -11013.94, 11027.75 -11047.49, 11047.49 -11086.98, 11086.98 -11126.48,11126.48 -11146.24 Tubing ( size, grade, and measured depth): 7" 29# L-80 @ 44 10785 Packers & SSSV (type & measured depth): 7" Baker SABL-3 Packer 7" HES HRQ SSV 7" Liner Top Packer @ 10730 @ 2037 10781 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Averaqe Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 13 Oil-Bbl Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ] Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D OilO GasO WAG D GINJŒ) WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: 303-162 Well Integrity Coordinator Title Daily Report of Well Operations - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Anders/Anna Dube Printed Name ~a/Jube () Signature '-- ( -->{ A. Ã-A....(" - .lJ.. U Phone 659-5102 de2, 4 1(~ir4 Form 1 0~404 Revised 12/2003 U~IGINAL.. -8Ft. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ( ( ( 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program D 2. Operator Name: Suspend D Repair Well 0 Pull Tubing D Operation Shutdown 0 Plug Perforations D Perforate New Pool D 4. Current Well Class: PerforateD WaiverŒ) Annular DisposalD StimulateD Time ExtensionD OtherO Re-enter Suspended WellD 5. Permit to Drill Number: 201-0600 BP Exploration (Alaska), Inc. Development 0 Exploratory 0 StratigraphicO Service ŒJ 9. Well Name and Number: NS31 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY , I Effective Depth MD (ft): I Effective Depth TVD (ft): 11356 11141.7 S~ MD WD 6. API Number 50-029-23009-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.00 KB 8. Property Designation: ADL-312799 11. Total Depth MD (ft): ¡Total Depth TVD (ft): 11440 11280.8 Casing Length Plugs (md): Junk (md): None None Burst Collapse Conductor 153 Liner 671 Production 10884 Surface 3192 Perforation Depth MD (ft): 11150 - 11170 11184 - 11204 11204 - 11244 11244 - 11284 11284 - 11304 Packers and SSSV Type: 7" Baker SABL-3 Packer 7" HES HRQ SSV 7" Liner Top Packer 12. Attachments: Description Summary of Proposal Œ) 20" 169# X-56 7" 29# 13Cr80 9-5/8" 53.5# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 10994 - 11013.9 11028 - 11047.5 11047 - 11087.0 11087 - 11126.5 11126 - 11146.2 top bottom top bottom 46 - 199 46.0 . 199.0 4260 2590 10768 - 11439 10618.2 - 11279.8 8160 7020 43 - 10927 43.0 - 10774.5 7930 6620 45 3237 45.0 - 3233.6 4930 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 7 " 29 # L-80 44 - 10785 Packers and SSSV MD (ft): 10730 2037 10781 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 ExploratoryD DevelopmentD ServiceŒ) 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: 15. Well Status after proposed work: Oil D GasD WAG D GINJŒ] Plugged D Abandoned D WINJD WDSPLD Prepared by Garry Catron 564-4657. July 1,2004 Contact Anna Cube I Joe Anders Printed Name -- ~na Dube /J A - Title Signature..... C)(./\.ÄA Á ~ A (~~..AJl- Phone Commission Use Only Well Integrity Coordinator 659-5102 6/18/04 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: Plug Integrity D BOP TestD Mechanciallntegrity Test D Location Clearance D Other: Subsequent Form Required: Approved by: BY ORDER OF THE COMMISSION Date: Form 10-403 Revised 12/2003 SUBMIT IN DUPLICATE ( t ( NS31 Description Summary of Proposal 06/18/04 Problem: Gas Injector with Slow TxlA Communication Well History and Status Well NS31 (PTD 2010600) is a gas injector that exhibits slow TxlA communication exhibited in slow IA re-pressurization. Bleeds are occurring approximately once every 2 months to keep the IA pressure below 3000 psi. The IA pressure is observed to increase as much as 300 psi/day, depending on injection temperature and pressure. On 12/08/01, an MITIA passed to 2700 psi with the well on injection. Summary of recent events: > 06/01/01: Rig conducted MITIA Passed to 5500 psi > 12/08/01: AOGCC witnessed MITIA Passed to 2700 psi > 01/02/03: NFT-IA Passed This sundry request is to allow for continued gas injection. The following supports the request: - An MITIA passed to 2700 psi on 12/08/01, demonstrating competent production casing. - The IA repressurization rate is low, averaging approximately 15 psi/day. - Pressures, temperature and injection rate are monitored and recorded daily. - The production casing is rated to a burst pressure of 7930 psi, 440/0 greater than injection pressure. Proposed Action Plan 1. Allow well to continue gas injection. 2. Limit the IA operating pressure to 3000 psi. 3. Record wellhead pressures, temperature, and injection rates daily. Also record IA bleeds. 4. Submit a monthly report of daily pressures, temperatures, and injection rates. 5. Perform a MITIA once every 2 years. 6. Notify the AOGCC if the bleed rate increases significantly. TREE: ABB-VGI 7" 6.5 ksi WELLHEAD:ABB-VGI 13-5/8" 6.5 ksi Multìbowl ~. (' NS31 (' .B. ELEV = 56' KB-BF. ELEV = 40.6' BASE FLANGE ELEV = 15.4' HRQ SSSV @2037' MD 2034' TVD 7" HRQ SVLN 5.963" ID 13 3/8", 68#/ft, L-80, BTC @323T ... ~ 6.8PPG DIESEL FREEZE PROTECTION AT +/- 2700 7", 29#/ft, 13Cr, NSCC TUBING ID: 6.184" CAPACITY: 0.037 BBL/FT SAFETY NOTES: SLOW TUBING x IA COMM Operating Pressure of the 9 5/8" Annulus MUST NOT Exceed 3000 psi (11-21-02 Waiver) 7" R NIPPLE, @10709' 5.963" ID (OTIS) 7" R NIPPLE, @ 10755' 5.963" ID (OTIS) 7" RN NIPPLE, @10767' 5.77" ID (OTIS) 7" WLEG, @10785' ~!. 6.184" ID (OTIS) 9 5/8" 53.5#/ft L-80, BTC-M @1 0927' ~. r Baker SABL-3 PACKER . 6.00" 10 @10730' MO 10579' TVO ~ 7" LINER TOP @10781' MD l 10629' TVO 6.184" 10 Ftff(R\T(NSJVM:IR( R:FLœ ŒAIT(5'22'01) [r&hl.qJ: CRCXlJL81] AN3..EA T1(PJ=ffP. N:Xe: RtertoR'cd.d:ìa1 œfcrlistaica p:rf œca htía Rrl- Qa-g:r 4815 FbNer J:t,1-M<; R:n:tra:b1: 5:f'; H:Ie: .42'; RBse: 72 Œg SZE s:F NllR/ÆfvD NllR/Æ 1VD Q:rl&:¡z D\lE 4.5 5 111M -11~ 11Ctæ-11144 QJ'1 7/14/m 4.5 5 1118J-1117U 1croz-11012 QJ'1 11/19'21)1 0 PBTD @11356' MD 11195' TVD TD @11439' j. ~ 7", 29#, 13Cr DATE 6/4/01 , 7/24/01 9/10/01 l~~ REV. BY AGK EMf- EMF EMF t:Mt- COMMENTS . , Initial DiaQram Add Perf Inserted TVD Depths Add Perf Updated KI:i & Safety Info NQrthstar YVFI ,I: NS31 API NO:50-0?9-?3009-00 BP Exploration (Alaska) ( ( ( NS-31 TIO Plot 6,000 -.- Tbg . fA -.- OA ~ ¡ffJ~~ I., ' \ r ~,ii ¡ ¡ Ii. ~. ~. ;.: ! ' . " .-., i . ' ~.: ' . .' f t ~ It I i ¡~ ~ ì¡ : " t 11: " ,: OOA [I OOOA ::~ A .'J~ I 6/19/2004 2/19/2004 ¡ I D ! ii :1 ~f " ~ I l.â. \, r¡I! f¡ ~'11 d II ~ I· I 10/19/2003 12/19/2003 ~I"';I,, '! I I ' I \ Ii . ¡ !~" I: : I ,¡ : ! Ii ~ Ii 5,000 4,000 3,000 cu ~ ::::s U) U) cu ~ a.. 8/19/2003 2,000 o 6/19/2003 ,000 bp ) ) BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561·5111 March 22, 2004 Howard Okland Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 Mr. Jeffrey Walker Regional Supervisor Field Operations Minerals Management Service 949 East 36th Avenue, Suite 308 Anchorage, Alaska 99508-4363 SCANNED FEf3 0 1 2005 Dear Mr. Okland and Mr. Walker Northstar Reports Please find the following reports enclosed in response to a recent request for some data from Robert Crandall. ,;¡(-; I - (! :;:) C, NS 13 - Reservoir fluids - Kuparuk Sample (Sample - Downhole RFT) :1CR} - ) L.t I NS18 - Preliminary Recombination Results (Sample - Separator Oil and Gas) Ç;1. .(.. I')V-O NS31 - Reservoir Fluids - Ivishak Sample (Sample - Downhole MDT) ~~ 0' ,- v'V For NS27 fluid samples were not taken in the Ivishak. Some RFT samples were taken in the Kuparuk, however they were flashed at the surface and only used for geochem analysis. There is some compositional analysis and PVT work on samples from NS09, NS13, NS08 and NS15 but the report has not yet been finalized. There was a request for the NS20 completion package. A copy of Form 10-407 for NS20 has been enclosed. This was submitted to the agencies on 9/15/03. The final logs for NS20 are not yet available, as we were unhappy with the original primary depth control log. A new primary depth control log will be acquired as soon as it is logistically feasible, but please let us know if you would like us to provide you with field prints in the interim. Sincerely, 1ÝA~~~ Micqael J. Fr I Senior Petrole Engineer Northstar, BP - Alaska l~~Fr')Ei'~~~'~~'1 t~I--:'n\-- .~l...;",<:t,.,.'i"."--" .. ,~ t l "'-l~~ ",' ·.....1......JG I ~' "', ') - -. . ;11I'.......; ...... {.~/.~ l'j _/þ t!. ')!}D .' ~ I' Ii ~ fA::;;} ~·..l ¡4, File: AOGCC :'-J;-.!~I(f,d·n9 {,'~;"<i-' r·-" ,.", >~_. _.. . . ,,\,.,-,,<,-,~~,;(~,.q '--,"n N)~Y'!;, ~ ·n~~~M~\Wïi.'~\·1 " '. -f'-;:~:~~ f;~ ::";-~ .~:,~ ~ '\I!,·,~\:~,\t~ (¡ ",¡·)J,,~¡,~[~t. , '" ¡' " ':,11, ~I'_,::~ :11/· ~I!" ) ) WESTPORT ...·"'..........,,...__...................M."..........................._......,'.._..... TECHNOLOGY CI:."'mR INTERNATIONAL ....-......-..............-- Reservoir Fluids PF~02~002 January 2002 d.,p t ~ o&ó NORTHSTAR WELL NS-31 IVISHAK SAMPLE Work By: C. Irani and R. Petruska Westport Technology Center International 6700 Portwest Drive Houston, Texas 77024 (281) 560-4666 (713) 864-9357 (Fax) www.westport1.com RECEIVED tJ ^ D ? ~ ?!\Ï\Lt ¡ ;¡-.. \ ~ V ,-Vv l~ja~~8 on &. Gas Cons. Commision f\,nch0fage Prepared for BP-Alaska W.O.#: M21204MOOO Westport Technology Center International makes no representations or warranties, either expressed or implied, and specifically provides the results of this report "as is" based on the information provided bv client. WESTPORT TECHNOLOGY CENTER INTERNATIONAL SAMPLE SUMMARY A total of 10 high-pressure hydrocarbon samples were collected by BP Exploration Alaska at the Northwest Field Well NS-31. The samples were collected at each of the following depths: 11077ft, 11096ft, 11144ft, 11187ft, and 11271 ft MD. An additional MPSR along with three MRSC (1 gallon) and a MRSC (2 3/4) high-pressure cylinder was taken at a depth of 11224ft MD. The samples were transferred from the field to a base location for further studies. The sample chambers have been restored to 8000Psi and 200°F before being transferred into conventional sample bottles. The MRSC (2 % gallon) was transferred into a 20 liter sample cylinder, and the two remaining MRSC'S (1 gallon) were combined into one 20 liter sample cylinder. Except for one 20 liter sample cylinder (MM33064, Sample No. 1.12) which was shipped to the S.L. Ross Environmental lab in Canada, all the remaining sample were delivered to Westport Technology center for additional studies. DISCUSSION Out of 6 MPSR's, samples 1.01 through 1.04 were found to have no sample (oil) contents. The two remaining MPSR's samples 1.13 and 1 .14 contained 250cc and 75cc of sample respectively. A single stage direct flash was performed on the two samples (1.13 and 1.14) and GOR / C36+ recombined composition is presented in Tables 7 and 8. Compositions of these two samples (1.13 and 1.14) was found to be sufficiently different on a basis of lower GOR and composition from that of the MRSC 226 samples (1.06 - 1.10) collected from the same depth of 11 ,224ft. Sub samples of 1 .06 - 1.10 (MRSC 226) collected from 1 gallon MDT Chamber have been restored for five days at 8000Psi and 200°F prior to individual single stage direct flashes at atmospheric conditions. Summary data from this process step can be found on the Table 1 with more detailed compositional description on the Tables 2 through 6. Upon comparing the GaR / C36+ composition from each flash, along with the client's approval, the MRSC 226 sub samples were combined to a single Westport cylinder. A single stage direct flash was performed on the combined composition of 1.06-1.10 to ensure the quality of the sample prior to further studies as seen in Table 9. All the empty high pressure cylinders have been returned to Schlumberger to stop the rental cost The results from a constant composition study on the combined sample of 1.06-1.10 are presented in Table 10. At the reservoir temperature of 254°F the sample had a bubble point pressure of 4715Psia with density of O.5144g/cc at the same pressure. Prepared for BP-Alaska 1/14/02 PF-02-002 Page 1 ) ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL Viscosity data in the single and two-phase region are presented in Table 11. At the reservoir temperature of 254°F and bubble point pressure of 4715Psia, the liquid was found to have viscosity of 0.2030 cP. A five-stage differential liberation study was performed at the reservoir temperature of 257°F with the respective oil properties summarized on the Table 12 and that for gas properties on Table 13. Compositional gas properties collected at each stage of the differential liberation along with the dead oil properties are summarized in Table 14. Results from a four-stage separator study are summarized in Table 15. The total separator study gave a total GOR of 2135.9 SCF/STB, a formation volume factor of 2.292 Res.Bbls/STB, and a residual oil API of 42.12. Gas properties collected from the separation test at each stage are summarized in Table 16 and the C36+ composition of the residual oil in Table 17. Prepared for BP-Alaska 1/14/02 PF-02-002 Page 2 WESTPORT TECHNOLOGY CENTER INTERNATIONAL Table 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Prepared for BP-Alaska 1/14/2002 LIST OF SAMPLES BP Exploration Alaska, Northstar Well NS-31, Ivishak Sample Sample No. / Bottle No. 1.06 -1.14 1.06 - 1.14 1.06 6610-MA 1.07 7163-MA 1.08 7147-MA 1.09 7168-MA 1.10 6987-MA 1 .13 6649-MA 1.14 6198-MA 1.06-1.10 Combined Sample 1.06-1.10 Combined Sample 1 .06-1 .10 Combined Sample 1.06-1.10 Combined Sample 1 .06-1 .10 Combined Sample 1.06-1.10 Combined Sample 1.06-1.10 Combined Sample 1.06-1 .10 Combined Sample 1.06-1.10 Combined Sample Work Summary Ivishak Sample Table of Contents Ivishak Sample Summary GOR I C36+ Recombined Composition GOR / C36+ Recombined Composition GOR I C36+ Recombined Composition GOR I C36+ Recombined Composition GOR / C36+ Recombined Composition GOR I C36+ Recombined Composition GOR / C36+ Recombined Composition GOR / C36+ Recombined Composition Constant Composition Expansion at 254°F Viscosity Measurements at 254°F Oil Properties from Differential Liberation Gas Properties from Differential Liberation C36+ Recombined Composition From Differential Liberation Multistage Separation Study Summary Gas Properties from Separation Study Oil Properties from Separation Study PF-02-002 Page 3 · . WEST PORT TECHNOLOGY CENTER INTERNATIONAL TABLE 1 BP Exploration Alaska, Northstar Well NS-31, Ivishak Sample Summary Bottle No. Sample No. Sample Density at ºAPI Gas Gravity, GOR (SCF/STB) STO Density Sample Depth (ft.) 8000 Psia & 200ºF (Air = 1) (glcc) 6610-MA 1.06 0.5232 40.641 0.8046 2225.80 0.8213 11 ,224 7163-MA 1.07 0.6276 42.271 0.7642 2103.72 0.8136 11,224 - 7147-MA 1.08 0.6417 42.484 0.7637 2164.54 0.8126 11 ,224 7168-MA 1.09 0.6504 42.399 0.7635 2150.80 0.8130 11,224 6987 -MA 1.10 0.6542 42.506 0.7714 2095.95 0.8125 11 ,224 6649-MA 1.13 0.6428 41.547 0.7784 1627.71 0.8170 11 ,224 6198-MA 1.14 0.6564 41.357 0.7734 1499.68 0.8179 11 ,271 .-- Prepared for BP-Alaska 1/14/2002 PF-02-002 Page 4 WESTPORT TECHNOLOGY CENTER INTERNATIOr-."L TABLE 2 BP Exploration Alaska, Northstar Well NS-31 , Ivishak Sample: 1.06 661G-MA, Single Stage Liquid Flash Compositions, Sample Depth: 11.224 ft. Single Stage Flash GOR I ~:?26 Scf:'STB STO Composition Flashed Gas Compositions Gas SG 0.3046 Sto Density 0.8213 gm/cc BO(){} PSIA ?OOF Den:,lty 0.5232 Cal Mw> 174.8 Cal Mw> 23.3 Coli r....'w;> 55,0 Gas Oil Gas Oil Gas Oil Vol (CC) f 1.000 I 01.0°1 2267.93 5.721 Density (gmlCC) 0.8213 9m1cc 1.04E-03 1.042E·03 0.8213 2.,3()24 4.6986 API 40.641 Molo%. ì9.04~o 20.96':, WI '%, 33.46% 66.54";) 2226 Scf/STB Mole Wt Component Wt% Mole % Wt% Mole % r 5.84 Wt% Mole% MW (Katz Et 81) Hydrogen Sulfide 0.000 0.000 GallMcf 34.080 Nitrogen 0.000 0.000 0.818 0.680 0.274 0.538 28.013 Carbon Dioxide 0.000 0.000 10.003 5.298 3.347 4.186 44.010 Methane 0.000 0.000 50.825 73.843 17.005 58.346 16.043 Ethane 0.002 0.013 11.213 8.691 2.320 3.753 6.870 30.070 Propane 0.081 0.321 11.821 6.248 1.718 4.009 5.004 44.097 iso-Butane 0.132 0.396 2.503 1.004 0.328 0.925 0.876 58.123 n-Butane 0.563 1.693 5.459 2.189 0.690 2.201 2.084 58.123 iso-Pentane 0.746 1.807 1.720 0.556 0.203 1.072 0.818 72.150 n-Pentane 1.231 2.981 1.867 0.603 0218 1.444 1.101 72.150 CG 3.047 6.340 1.373 0.371 0.144 2.487 1.630 84.000 Benzene 0.262 0.585 0.075 0.022 0.006 0.199 0.140 78.120 C7 5.671 10.326 1.134 0.264 0.109 4.153 2.382 96.000 Toluene 0.725 1.375 0.123 0.031 0.010 0.524 0.313 92.150 C8 7.627 12.459 0.630 0.129 0.059 5.286 2.719 107 C9 6.260 9.043 0.243 0.044 0.022 4.247 1.932 121 C10 5.651 7.372 0.101 0.016 0.009 3.794 1.559 134 C11 4.614 5.486 0.037 0.006 0.004 3.083 1.154 147 C12 4.129 4.483 0.011 0.002 0.001 2.751 0.941 161 C13 4.504 4.499 0.044 0.003 0.002 3.012 0.947 175 C14 4.158 3.826 2.767 0.802 190 C15 3.906 3.314 100.00 100.00 2.599 0.695 206 C16 3.366 2.650 2.240 0.555 222 cn 3.138 2.314 Heating Values BTU/CF 2.088 0.485 237 C18 3.140 2.186 Grossi 1255 2.089 0.458 251 C19 2.894 1.923 Net 1140 1.926 0.403 263 C20 2.456 1.561 1.634 0.327 275 C21 2.210 1.327 1.470 0.278 291 C22 2.088 1.197 MVV 23.304 1.390 0.251 305 C23 1.930 1.061 sa 0.80·1G 1.284 0.222 318 C24 1.739 0.918 Z STY 0..9926 1.157 0.192 331 C2S 1.624 0.823 1.081 0.172 345 C26 1 .523 0.742 Ç_<!.!L,Ç.!:!!ifI.ILL& P 1.014 0.155 359 C27 1.476 0.690 ("Fi -44 0.983 0.145 374 C28 1.407 0.634 WSIl\) 6'79 0.936 0.133 388 C29 1.340 0.582 0.891 0.122 402 C30 1.226 0.515 0.616 0.108 416 C31 1.142 0.464 0.760 0.097 430 C32 1.024 0.403 0.681 0.084 444 C33 0.957 0.365 0.637 0.077 458 C34 0.894 0.331 0.595 0.069 472 C3S 0.857 0.308 0.570 0.065 487 C3G 10.262 2.685 6.829 0.563 668 100.000 100.000 100.000 100.000 Prepared lor BP·Alaska 1/1 412002 PF-02-002 Page 5 ') ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 3 BP Exploration Alaska, Northstar Well NS-31, Ivishak Sample: 1.07 7163-MA, Single Stage Liquid Compositions, Sample Depth: 11.224 ft. Single Stage Flash GOR I 2104 Scf/STB STO Composition Flashed Gas Compositions Gas SG 0.7642 Sto Density 0.8136gm/cc 8000 PSIA 200°F Density 0.6276 Cal Mw> 169.5 Cal Mw> 22.1 Cal Mw> 56.1 Gas 011 Gas Oil Gas 011 Vol (CC) \ 1.000 01.00\ 2573.16 6.868 Density (gmlCC) 0.8136 gm/cc 9.45E-04 9.453E-04 0.8136 2.4325 5.5875 API 42.271 Mole % 76.93% 23.07% Wt% 30.33% 69.67% 2104 Scf/STB Mole Wt Component Wt% Mole % Wt% Mole % S 5.09 Wt% Mole % MW (Katz Et al) Hydrogen Sulfide 0.000 0.000 Gal/Mcf 34.080 Nitrogen 0.000 0.000 0.981 0.775 0.298 0.596 28.013 Carbon Dioxide 0.000 0.000 10.877 5.471 3.299 4.208 44.010 Methane 0.000 0.000 54.870 75.706 16.642 58.230 16.043 Ethane 0.009 0.048 12.452 9.166 2.447 3.783 7.061 30.070 Propane 0.296 1.136 11.332 5.689 1.564 3.643 4.637 44.097 Iso-Butane 0.331 0.966 2.009 0.765 0.250 0.840 0.811 58.123 n-Butane 1.219 3.555 3.821 1 .455 0.458 2.008 1.940 58.123 Iso-Pentane 1.082 2.541 0.943 0.289 0.106 1.040 0.809 72.150 n-Pentane 1.624 3.815 0.956 0.293 0.106 1.421 1.106 72.150 C6 3.326 6.711 0.630 0.162 0.063 2.508 1.676 84.000 Benzene 0.278 0.603 0.035 0.010 0.003 0.204 0.147 78.120 C7 5.713 10.086 0.518 0.115 0.047 4.137 2.419 96.000 Toluene 0.752 1.383 0.031 0.008 0.003 0.533 0.325 92.150 C8 7.393 11.712 0.302 0.059 0.027 5.242 2.750 107 C9 6.030 8.447 0.132 0.023 0.011 4.241 1.967 121 C10 5.417 6.852 0.054 0.008 0.004 3.791 1.588 134 C11 4.400 5.073 0.020 0.003 0.002 3.071 1.173 147 C12 3.946 4.154 0.007 0.001 0.001 2.751 0.959 161 C13 4.305 4.170 0.030 0.002 0.001 3.008 0.965 175 C14 3.962 3.535 2.761 0.816 190 C15 3.711 3.053 100.00 100.00 2.585 0,704 206 C16 3.184 2.431 2,219 0.561 222 C17 2.997 2.143 Heating Values BTU/CF 2.088 0.495 237 C18 2.979 2.012 GrossI 1187 2.076 0.464 251 C19 2.749 1.772 Net 1076 1.915 0.409 263 C20 2.336 1 .440 1.627 0.332 275 C21 2.112 1.230 1.472 0.284 291 C22 1.986 1.104 MW 22.134 1.384 0.255 305 C23 1,813 0.966 SG 0.7642 1.263 0.223 318 C24 1.654 0.847 ZSTP 0.9932 1.153 0.195 331 C25 1.517 0.745 1.057 0.172 345 C26 1.425 0.673 Calc Critical T & P 0.993 0,155 359 C27 1.370 0.621 (OF)I -55 0.954 0.143 374 C28 1.289 0.563 (PSI A) 683 0.898 0.130 388 C29 1.210 0.510 0.843 0.118 402 C30 1.101 0,449 0.767 0.103 416 C31 0.991 0.391 0.690 0.090 430 C32 0.857 0.327 0.597 0.075 444 C33 0.773 0.286 0.538 0.066 458 C34 0.687 0.247 0.478 0.057 472 C35 0.625 0.218 0.436 0.050 486 C36 12.552 3.185 8.745 0.735 668 100.000 100.000 100.000 100.000 Prepared for BP·Alaska 3/22/2004 PF-02·002 Page 6 WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 4 BP Exploration Alaska, Northstar Well NS-31 , Ivishak Sample: 1.08 7147·MA, Single Stage Liquid Flash Compositions, Sample Depth: 11.224 ft. S".le St'r Fl." GOR 2165 Sct/STB STO Composition Flashed Gas Compositions Gas SG 0.7637 Sto Density 0.8126 gmlcc 8000 PSIA 200°F Density 0.6417 Cal Mw> 169.0 Cal Mw> 22.1 Cal Mw> 55.4 Gas Oil Gas Oil Gas Oil Vol (CC) I 1.000 I 01.001 2662.96 6.908 Density (gmlCC) 0.8126 gm/cc 9.41E-04 9.414E-04 0.8126 2.5069 5.6131 API 42.484 Mole% 77.33% 22.67% Wt% 30.87% 69.13% 2165 Scf/STB Mole Wt Component Wt% Mole % Wt% Mole % S 5.05 Wt% Mole % MW (Katz Et al) Hydrogen Sulfide 0.000 0.000 Gal/Met 34.080 Nitrogen 0.000 0,000 0,867 0,685 0.268 0.529 28.013 Carbon Dioxide 0.000 0.000 10.925 5.492 3,373 4,247 44,010 Methane 0,000 0.000 55,083 75.965 17,006 58.735 16.043 Ethane 0,018 0.102 12.351 9088 2.426 3.826 7.050 30.070 Propane 0,381 1.459 11.098 5.569 1.531 3.690 4,636 44.097 iso-Butane 0.368 1.069 1,970 0.750 0.245 0,862 0.822 58,123 n-Butane 1.308 3,803 3.750 1.428 0.450 2.062 1.966 58.123 iso-Pentane 1,109 2.597 0.939 0.288 0.105 1.056 0.811 72.150 n-Pentane 1.652 3.870 0.957 0.293 0,106 1.438 1,104 72,150 C6 3.329 6.697 0.648 0.166 0.064 2.501 1.650 84,000 Benzene 0.278 0.600 0.036 0,010 0.003 0,203 0.144 78.120 C7 5.680 9,998 0.560 0.124 0.051 4.099 2.366 96.000 Toluene 0.747 1.370 0.044 0.011 0.004 0,530 0.319 92,150 C8 7.341 11.593 0,364 0,070 0,032 5.187 2.686 107 C9 5.977 8,347 0.185 0.032 0.016 4.189 1.918 121 C10 5,365 6.766 0.098 0.015 0,008 3.739 1,546 134 C11 4,354 5.005 0,052 0.008 0.005 3.026 1.140 147 C12 3.907 4,101 0,024 0,003 0,002 2,708 0.932 161 C13 4.261 4.115 0.049 0,003 0.002 2.961 0,938 175 C14 3.904 3.473 2,699 0,787 190 C15 3,690 3.027 100,00 100.00 2.551 0.686 206 C16 3.127 2.380 2.162 0,540 222 C17 2.956 2,108 Heating Values BTU/CF 2,044 0.478 237 C18 2,935 1. 976 Grassl 1187 2,029 0.448 251 C19 2.725 1.751 Net 1077 1. 884 0,397 263 C20 2.265 1,392 1.566 0.315 275 C21 2.081 1.208 1.438 0,274 291 C22 1,966 1.089 MW 22.120 1,359 0,247 305 C23 1,809 0.962 SG 0.7637 1.251 0.218 318 C24 1.633 0,834 ZSTP 0,9932 1.129 0.189 331 C25 1,520 0,744 1,051 0.169 345 C26 1.422 0.669 C¡¡lc Critical T & P 0,983 0,152 359 C27 1.356 0613 (OF)/ -55 0,937 0,139 374 C28 1,291 0,562 (PSIA) 683 0,893 0,127 388 C29 1.220 0.513 0,843 0.116 402 C30 1.108 0.450 0,766 0,102 416 C31 1,001 0.393 0.692 0.089 430 C32 0.876 0.333 0.605 0.076 444 C33 0.782 0,288 0.540 0.065 458 C34 0,702 0.251 0.485 0.057 472 C35 0.644 0.224 0.445 0,051 486 C36 12,914 3,267 8,927 0.740 668 100,000 100,000 100.000 100.000 Prepar(;tJ for BP-Alaska 3/22/2004 PF-02-002 Page 7 ) ) WEST PORT TECHNOLOGY CENTER INTERNATIONAL TABLE 5 BP Exploration Alaska, Northstar Well NS-31 , Ivishak Sample: 1.09 7168-MA, Single Stage Liquid Flash Compositions, Sample Depth: 11.224 ft. Single Stage Flash STO Composition Flashed Gas Compositions GOR. I 2151 Scf/STB Gas SG 0.7635 Sto Density 0.813 gm/cc äooo~pslÄ 200"F . ì De~sity O.~)504 Cal Mw> 167.7 Cal Mw> 22.1 Cal Mw> ~ Gas 011 Gas 011 Gas 011 Vol (CC) 1.000 01.001 í"2~Ø'11.~; , 1 . . . ?-~p~ Density (gm/CC) 0..8139m/cc 9.45E-04 I !lK4~SOIËHJ·4 tJL~11301 I I "':',V:~'''''\-\', ',~'\~\:,:\:,~ 2.~"'11 ~fi'~'~'~.. ....' API 42.399 Mole% 77.15% 2,;~' ¿1~T'1'III~ , Wt% 30.81% 89 1~1'" 2151 Scf/STB Mole Wt Component Wt% Mole% Wt% Mole % S 5.04 Wt% Mole % MW (Katz Et 81) Hydrogen Sulfide 0.000 0.000 GaVMcf 34.080 Nitrogen 0.000 0.000 0.973 0.769 0.300 0.593 28.013 Carbon Dioxide 0.000 0.000 10.834 5.445 3.338 4.200 44.010 Methane 0.000 0.000 55.111 75.9T1 16.979 58.604 16.043 Ethane 0.014 0.077 12.368 9.097 2.428 3.820 7.035 30.070 Propane 0.348 1.324 11.007 5.521 1.518 3.632 4.561 44.097 Iso--Butane 0.353 1.019 1.951 0.742 0.242 0.846 0.806 58.123 n-Butane 1.272 3.671 3.711 1.412 0.445 2.024 1.928 58.123 iso·Pentane 1.099 2.554 0.930 0.285 0.104 1.047 0.804 72.150 n-Pentane 1.642 3.817 0.949 0.291 0.105 1.429 1.097 72.150 C6 3.337 6.661 0.651 0.167 0.065 2.509 1.654 84.000 Benzene 0.280 0.600 0.036 0.010 0.003 0.205 0.145 78.120 C7 5.733 10.014 0.573 0.127 0.052 4.144 2.390 96.000 Toluene 0.872 1.586 0.032 0.008 0.003 0.613 0.368 92.150 C8 7.424 11.634 0.391 0.076 0.034 5.258 2.721 107 C9 6.059 8.396 0.215 0.037 0.018 4.259 1.949 121 C10 5.453 6.823 0.118 0.018 0.010 3.809 1.574 134 C11 4.434 5.057 0.064 0.010 0.006 3.087 1.163 147 C12 3.974 4.139 0.029 0.004 0.003 2.759 0.949 161 C13 4.351 4.168 0.057 0.004 0.003 3.028 0.958 175 C14 3.980 3.512 2.754 0.802 190 C15 3.752 3.054 100.00 100.00 2.596 0.698 206 C16 3.200 2.417 2.214 0.552 222 C17 3.012 2.131 Heating Valuos BTU/CF 2.084 0.487 237 C18 2.999 2.004 Grossi 1166 2.075 0.458 251 C19 2.782 1.774 Not 1076 1.925 0.405 263 C20 2.360 1.439 1.633 0.329 275 C21 2.133 1.229 1.476 0.281 291 C22 2.001 1.100 MW 22.114 1.384 0.251 305 C23 1.848 0.974 SG 0.7635 1.279 0.223 318 C24 1.668 0.845 ZSTP 0.9932 1.154 0.193 331 C25 1.548 0.752 1.071 0.172 345 C26 1.455 0.679 Calc Critical T &P 1.006 0.155 359 C27 1.394 0.625 ("F)\ ·55 0.964 0.143 374 C28 1.311 0.567 (PSIA) 68:, 0.907 0.129 388 C29 1.245 0.519 0.862 0.119 402 C30 1.133 0.457 0.784 0.104 416 C31 1.015 0.396 0.702 0.090 430 C32 0.891 0.336 0.616 O.OTl 444 C33 0.808 0.296 0.559 0.068 458 C34 0.730 0.259 0.505 0.059 472 C35 0.651 0.225 0.451 0.051 486 C36 11.440 2.871 7.915 0.656 668 100.000 100.000 100.000 100.000 prepared lor Bp·Alaska 1/1412002 PF.Q2-OO2 Page 8 WESTPORT TECHNOLOGY CENTER INTERNATIOI\I",- TABLE 6 BP Exploration Alaska, Northstar Well NS-31, Ivishak Sample: 1.10 6987-MA, Single Stage Liquid Flash Compositions, Sample Depth: 11.224 tt. S;'9" SIr FI.,h GOR 2096 sc!/sn, STO Composition Flashed Gas Compositions Gas SG 0.7714 Sto Density 0.8125 gm/cc eoo·Q PSI;-I 20(,"F Den5ìty 06542 Cal Mw> 170.1 Cal Mw> 22.3 Cal Mw> 56.4 Gas Oil Gas Oil Gas 011 Vol (CC> I 1.000 J 01.001 2633.26 7.054 Density (gmlCC) 0.8125 gmlcc 9.55[·04 9.545E-04 0.8125 2513ß :'.7314 API 42.506 Mole % 76.95% 23,û5~.'o Wt% 30.49% 69S1~o 2096 Sef/STB Mole Wt Component Wt% Mole% Wt% Mole% S 5.11 Wt% Mole% MW (Katz Et al) Hydrogen Sulfide 0.000 0.000 Gal/Mcf 34.080 Nitrogen 0.000 0.000 0.959 0.765 0.292 0.589 28.013 Carbon Dioxide 0.000 0.000 11 .484 5.832 3.501 4.486 44.010 Methane 0.000 0.000 54.138 75.416 16.505 58.017 16.043 Ethane 0.013 0.074 12.264 9.115 2.433 3.748 7.029 30.070 Propane 0.367 1.415 11.032 5.591 1.537 3.618 4.627 44.097 Iso-Butane 0.369 1.081 1.942 0.747 0.244 0.849 0.824 58.123 n-Butane 1.313 3.842 3.681 1.415 0.446 2.035 1.974 58.123 iso-Pentane 1.109 2.614 0.934 0.289 0.106 1.056 0.825 72.150 n-Pentane 1.650 3.890 0.925 0.287 0.104 1.429 1.117 72.150 C6 3.343 6.770 0.647 0.168 0.065 2.521 1.693 84.000 Benzene 0.271 0.590 0.036 0.010 0.003 0.199 0.144 78.120 C7 5.634 9.982 0.615 0.137 0.056 4.104 2.411 96.000 Toluene 0.735 1.357 0.038 0.009 0.003 0.523 0.320 92.150 CB 7.267 11.551 0.481 0.094 0.043 5.198 2.740 107 C9 5.904 8.299 0.320 0.056 0.028 4.202 1.958 121 C10 5.303 6.731 0.216 0.034 0.018 3.752 1.579 134 C11 4.305 4.981 0.135 0.020 0.012 3.034 1.164 147 C12 3.857 4.074 0.063 0.009 0.006 2.700 0.946 161 C13 4.210 4.092 0.090 0.006 0.004 2.954 0.952 175 C14 3.851 3.448 2.677 0.795 190 C15 3.630 2.997 100.00 100.00 2.523 0.691 206 C16 3.099 2.374 2.154 0.547 222 C17 2.915 2.092 Heating Values ßTUiCF 2.026 0.482 237 C18 2.899 1.965 Grossi 1189 2.016 0.453 251 C19 2.690 1.739 N<:>t 1019 1.870 0.401 263 C20 2.285 1.413 1.588 0.326 275 C21 2.053 1.200 1.427 0.277 291 C22 1.943 1.084 r,,'~Vl 22342 1.351 0.250 305 C23 1.792 0.958 SG O,7ì11 1.245 0.221 318 C24 1.618 0.831 ZSH' O.993? 1.124 0.192 331 C25 1.510 0.745 1.050 0.172 345 C26 1.418 0.672 Ç£J]Lºr.w.rJ31 T & P 0.985 0.155 359 C27 1.369 0.623 ¡'F\ ·5:; 0.952 0.143 374 C28 1.288 0.564 (PSI,\) 6A4 0.895 0.130 388 C29 1.224 0.518 0.85'1 0.119 402 C30 1.113 0.455 0.774 0.105 416 C31 1.005 0.398 0.699 0,092 430 C32 0.880 0.337 0.612 0.078 444 C33 0.802 0.298 0.557 0.069 458 C34 0.737 0.266 0.512 0.061 472 C35 0.618 0.216 0.430 0.050 486 C36 13.611 3.465 9.461 0.799 668 100.000 100.000 100.000 100.000 Prepared for BP-AJaska 1/14/2002 PF-02-002 Page 9 ') ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 7 BP Exploration Alaska, Northstar Well NS-31 , Ivishak Sample: 1.13 6649-MA, Single Stage Liquid Flash Compositions, Sample Depth: 11.224 It. Slnqle Starn Flash GOR . 1628. Sel/STB STO Composition Flashed Gas Compositions !3!SJìG . ...0.7784 Sto Density 0.817 gm/cc 8<000 PSIA 200°F Den~ity 0,6428 Cal Mw> 172.7 Cal Mw> 22.5 CaI Mw> 64.2 Gas Oil Gas 011 Gas Oil Vol (CC)I ' 1 1.00D 01.001 I 2152.04 70423 Density (gmlCC) 0.817 gmlcc 9.57E-04 9.573E·04 0.8170 2.0601 . .. ~,.o649 API 41.547 Mole % 72.24% 27.76% Wt% 25.36% 74.64% 1628 ScflSTB Mole Wt Component Wt% Mole % Wt% Mole % S 5.48 Wt% Mole % MW (Katz Et al) Hydrogen Sulfide 0.000 0.000 Gal/Mef 34.080 Nitrogen 0.000 0.000 0.817 0.658 0.207 0.475 28.013 Carbon Dioxide 0.000 0.000 10.989 5.630 2.786 4.066 44.010 Methane 0.000 0.000 52.890 74.329 13.410 53.688 16.043 Ethane 0.Q11 0.065 12.850 9.636 2.572 3.267 6.977 30.070 Propane 0.305 1.196 12.172 6.224 1.711 3.314 4.827 44.097 iso-Butane 0.317 0.941 2.159 0.837 0.273 0.784 0.866 58.123 n-Butane 1.173 3.485 4.132 1.603 0.505 1.923 2.125 58.123 iso·pentane 1.002 2.398 1.018 0.318 0.116 1.006 0.895 72.150 n·Pentane 1.501 3.593 1.058 0.331 0.120 1.389 1.236 72.150 C6 3.076 6.325 0.697 0.182 0.070 2.473 1.891 84.000 Benzene 0.262 0.580 0.038 0.Q11 0.003 0.206 0.169 78.120 C7 5.372 9.665 0.568 0.128 0.053 4.154 2.779 96.000 Toluene 0.706 1.323 0.034 0.008 0.003 0.536 0.373 92.150 C8 7.032 11.351 0.332 0.066 0.030 5.333 3.201 107 C9 5.814 8.299 0.142 0.025 0.012 4.376 2.323 121 C10 5.293 6.823 0.056 0.009 0.005 3.965 1.901 134 C11 4.342 5.101 0.018 0.003 0.002 3.245 1.418 147 C12 3.936 4.223 0.007 0.001 0.001 2.940 1.173 161 C13 4.325 4.268 0.023 0.001 0.001 3.234 1.187 175 C14 4.025 3.659 3.005 1.016 190 C15 3.805 3.190 100.00 100.00 2.840 0.885 206 C16 3.267 2.542 2.439 0.706 222 C17 3.088 2.250 Heating Values BTU/ CF 2.305 0.625 237 C18 3.090 2.126 Gross I 1207 I 2.306 0.590 251 C19 2.867 1.883 Net 1095 2.140 0.523 263 C20 2.459 1.544 1.835 0.429 275 C21 2.211 1.312 1.651 0.364 291 C22 2.091 1.184 MW 22.545 1.561 0.329 305 C23 1.946 1.057 SG 0.7784 1.453 0.293 318 C24 1.741 0.908 ZSTP 0.9931 1.299 0.252 331 C25 1.633 0.818 1.219 0.227 345 C26 1.530 0.736 Calc. Critical T & P 1.142 0.204 359 C27 1.473 0.680 (oF) -50 1.100 0.189 374 C28 1.395 0.621 (PSIA) 684 1.041 0.172 388 C29 1.331 0.572 0.994 0.159 402 C30 1.204 0.500 0.899 0.139 416 C31 1.097 0.440 0.819 0.122 430 C32 0.965 0.376 0.721 0.104 444 C33 0.877 0.331 0.654 0.092 458 C34 0.806 0.295 0.602 0.082 472 C35 0.746 0.265 0.557 0.074 486 C36 11 .885 3.073 8.871 0.853 668 100.000 100.000 100.000 100.000 Prepared lor BP-Alaska 1/1412002 PF-02.()()2 Page 10 WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 8 BP Exploration Alaska, Northstar Well NS-31 , Ivishak Sample; 1.14 6194-MA, Single Stage liquid Flash Compositions, Sample Depth: 11.271 ft. STO Composhlon Flashed Gas Compositions Slo Density 0.8179 gm/cc Cal Mw> 178.5 Cal Mw> 22.4 Gas 011 Gas 011 Vol (CC) 1 1.000 , 01.001 Density (gmlCC), 0.8179 gmlcc 9.41 E-04 API 41.357 Component Wt% Mole % Wt% Mole % S 5.58 Hydrogen Sulfide 0.000 0.000 GaVMcf Nitrogen 0.000 0.000 0.833 0.666 Carbon Dioxide 0.000 0.000 9.360 4.765 Methane 0.000 0.000 53.569 74.809 Ethane 0.000 0.000 13.169 9.812 2.619 Propane 0.014 0.055 12.528 6.365 1.750 iso-Butane 0.000 0.000 2.195 0.846 0,276 n-Butane 0.000 0.000 4.231 1.631 0.514 iso·Pentane 0.000 0,000 1.061 0.329 0.120 n·Pentane 0.000 0.000 1.071 0.332 0.120 C6 7.479 15.891 0.716 0.186 0.072 Benzene 0.254 0.580 0.038 0.011 0.003 C7 5.353 9.953 0.590 0.132 0.054 Toluene 0.681 1.320 0.030 0.007 0.002 C8 7.007 11.689 0.344 0.067 0.030 C9 5.782 8.530 0.147 0.026 0.013 C10 5.256 7.002 0.063 0.010 0.005 C11 4.330 5.257 0.023 0.003 0.002 C12 3.903 4.327 0.008 0.001 0.001 C13 4.282 4.368 0.024 0.002 0.001 C14 3.987 3.745 C15 3.753 3.252 100.00 100.00 CIG 3.218 2.587 C17 3.032 2.284 Heating Values BTUI CF C18 3.021 2.148 Grossi 1221 C19 2.799 1.900 Net 1108 C20 2.406 1.562 C21 2.166 1.329 C22 2.073 1.213 l~y1'\V n·101 C23 1.887 1.059 SCì 0, Tl:14 C24 1.698 0.916 Z SIP 0.9930 C25 1.576 0.816 C26 1.478 0.735 (:"Iç Cn\'ç"lr &. P C27 1 .420 0.677 (F~l -b1 J C28 1.331 0.612 IPSIAI _.__.~.L C29 1.256 0.558 C30 1.137 0.488 C31 1.011 0.420 C32 0.861 0.346 C33 0.769 0.300 C34 0.682 0.258 C35 0.583 0.214 C3G 13.515 3.611 100.000 100.000 Prepared for 8P·Alaska 1/1412002 PF·02·002 Single Stare Flash GOR. 1500 SctiSïß Gas SG 0.773" P,':.IOO f'SI,; ?OO'F D",nsity 0.6664 Cd I MvV" 6'7.7 Gas Oil ~{I6~n(! l.ne< 9.;: ' ·'~.f,.C',: 1 ,911:LJ'i(~ Mole % 71.00% WI % 23.51% Wt% 0.196 2.200 12.593 3.096 2.955 0.516 0.995 0.249 0.252 5.889 0.203 4.233 0.528 5.441 4.458 4.035 3.317 2.987 3.281 3.049 2.871 2.462 2.319 2.311 2.141 1.840 1.657 1.586 1 .443 1.299 1.206 1.131 1.086 1.018 0.961 0.870 0.774 0.659 0.588 0.521 0.446 10.338 100.000 1500 ScffSTB Mole % 0.473 3.383 53.108 6.965 4.535 0.601 1.158 0.234 0.236 4.743 0.176 2.984 0.388 3.440 2.493 2.038 1.527 1.255 1.269 1.086 0.943 0.750 0.662 0.623 0.551 0.453 0.385 0.352 0.307 0.266 0.236 0.213 0.196 0.178 0.162 0.141 0.122 0.100 0.087 0.075 0,062 1.047 100.000 Mole WI MW (Katz Et 81) 34.080 28.013 44.010 16.043 30.070 44.097 58.123 58.123 72.150 72.150 84.000 "18.120 96.000 92.150 107 121 134 147 161 175 190 206 222 237 251 263 275 291 305 318 331 345 359 374 388 402 416 430 444 458 472 486 668 Page 1 ' ') ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL T AS LE 9 BP Exploration Alaska, Northstar Well NS-31 , Ivishak Combined Sample: 1.06 -1.10, Single Stage Liquid Flash Composition, Sample Depth: 11.224 ft. Single Stage Flash (¡On I 2134 Set/srB STO Composition Flashed Gas Compositions Gas SG O.·ti26 Sto Density 0.8144 gmlcc 10000 PSIA 72.3"F DElnsity 0.6621 Cal Mw> 165.8 Gal Mw> 22.4 Cal Mw> 56.0 Gas 011 Gas 011 (ill!'.., 011 Vol (CC) 1.000 01.Ö'o\ ~:~~:~,:~~, Density (gmlCC) 0.8144 glee 9..45E-04 I 1j ,,~,~2;~'.o.1i :,t~I"~:I¡j' API 42.100 Mole "i. 76.57% Wt% 30.60% 2134 Scf/STB MoleWt Component Wt% Molø% Wt% Mole 'Yo I 5.14 Wt'Yo Mole % MW (Katz Et al) Hydrogen Sulfide 0.000 0.000 GaVMcf 34.080 Nitrogen 0.000 0.000 0.968 0.773 0.296 0.592 28.013 Carbon Dioxide 0.000 0.000 11.414 5.804 3.493 4.443 44.010 Methane 0.000 0.000 53.989 75.313 16.523 57.655 16.043 Ethane 0.015 0.084 12.070 8.984 2.398 3.705 6.897 30.070 Propane 0.318 1.196 10.913 5.539 1.523 3.661 4.520 44.097 Iso-Butane 0.323 0.921 2.095 0.807 0.264 0.865 0.833 58.123 n·Butane 1.168 3.330 4.153 1.599 0.504 2.081 2.004 58.123 Iso-Pentane 1.072 2.464 1.105 0.343 0.125 1.082 0.840 72.150 n-Pentane 1.610 3.700 1.152 0.357 0.129 1.470 1.141 72.150 C6 3.439 6.787 0.790 0.205 0.079 2.628 1.751 84.000 Benzene 0.249 0.528 0.042 0.012 0.003 0.185 0.133 78.120 C7 5.945 10.267 0.648 0.145 0.060 4.324 2.521 96.000 Toluene 0.678 1.220 0.031 0.008 0.003 0.480 0.292 92.150 C8 7.760 12.023 0.364 0.071 0.032 5.496 2.875 107 C9 6.269 8.590 0.138 0.024 0.012 4.393 2.032 121 C10 5.635 6.971 0.066 0.009 0.005 3.927 1.641 134 C11 4.596 5.183 0.022 0.003 0.002 3.196 1.217 147 C12 4.096 4.218 0.009 0.001 0.001 2.845 0.989 161 C13 4.445 4.211 0.041 0.003 0.002 3.097 0.991 175 C14 4.114 3.590 2.855 0.841 190 C15 3.852 3.101 100.00 100.00 2.673 0.727 206 C16 3.303 2.467 2.292 0.578 222 C17 3.128 2.188 Heating Val\ es BTUlCF 2.170 0.513 237 C18 3.045 2.012 Gro'ssl 1191 2.113 0.471 251 C19 2.858 1.801 Net 1081 1.983 0.422 263 C20 2.417 1.457 1.677 0.341 275 C21 2.204 1.256 1.529 0.294 291 C22 2.066 1.123 MW 22.376 1.434 0.263 305 C23 1.672 0.976 SG 0,7726 1.299 0.229 318 C24 1.702 0.853 7.: STP 0,9931 1.181 0.200 331 C25 1.607 0.772 1.116 0.181 345 C26 1.482 0.685 Calc. Crlltilcal T & P 1.029 0.160 359 C27 1.411 0.625 rn\ -53 0.979 0.147 374 C28 1.369 0.585 (PSIA) 684 0.950 0.137 388 C29 1.237 0.510 0.859 0.120 402 C30 1.155 0.460 0.801 0.106 416 C31 1.026 0.396 0.712 0.093 430 C32 0.891 0.333 0.618 0.078 444 C33 0.809 0.293 0.561 0.069 458 C34 0.720 0.253 0.500 0.059 472 C35 0.662 0.226 0.460 0.053 486 C36 9.452 2.346 6.559 0.550 668 100.000 100.000 100.000 100.000 Prepared lor 6P-Alaska 1/1412002 PF.()2.()()2 Page 12 WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 10 BP Exploration Alaska, Northstar Well NS-31, Ivishak Combined Sample: 1.06 - 1.10, Constant Composition Expansion at 254°F, Sample Depth: 11.224 fl. Pressure Relative Volume Relative Liquid Volume (Psia) 8358.3 0.8914 8012.1 0.8962 7952.1 0.8996 7583.9 0.9077 7220.7 0.9171 6873.6 0.9255 6545.4 0.9351 6240.3 0.9429 5936.1 0.9515 5663 0.9619 5385.9 0.9709 5124.7 0.9814 4714.6 1 .0000 P Sat 4551 .5 1.0197 4340.4 1.0509 4145.3 1.0663 0.6473 3977.2 1.0841 0.6238 3829.1 1 .1 036 0.6109 3723.1 1 .1220 0.5947 3611 .1 1 .1373 0.5812 3506.9 1 .1 582 0.5678 3413.9 1.1758 0.5535 3232.8 1.2164 0.5184 2930.7 1 .2926 0.4541 Prepared for BP-Alaska 1/14/2002 PF-02-002 Page 13 ) ') WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 11 BP Exploration Alaska, Northstar Well NS-31, Ivishak Combined Sample: 1.06 -1.10, Viscosity Measurements at 254°F, Sample Depth: 11.224 ft. Pressure (Psia) 7775 6985 6217 5417 4810 4071 3476 2862 2264 1527 760 15 * Measured Data * Liquid Viscosity (cp) . 0.2280 0.2200 0.2100 0.2030 0.2000 0.2350 0.2650 0.3000 0.3400 0.4000 0.5000 0.7400 * Gas Viscosity (cp) 0.08 0.06 0.05 0.04 0.03 0.02 Viiscosi¡ty (CP) I :Pisiia ( .~:15 Ü.'75, . . - . . 10.. 0, ..," 011>5 ~. .., ~;)I g OS!) , ø' :; CD' O,,~~, 'õ. ~, (1,35 00' 1J2!~ 015 r' ~, 1000 :-;'000 .30~X¡ 4000 500::: t:.OOü !OO~l 8';:;,00 Pressure (psia) Prepared for BP-Alaska 1/14/2002 PF-02-002 Page 14 WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 12 BP Exploration Alaska, Northstar Well NS-31, Ivishak Combined Sample: 1.06 - 1.10, Oil Properties from Differential Liberation at 254 DF, Sample Depth: 11.224 ft. Pressure Temperature Oil Density Oil Relative Volume For. Vol. Factor Soln. GOR (Psia) (OF) (glee) (Res.Bbls I STB) (SCF/STB) 4732 254 0.5072 1 .0000 2.8307 2976 3781 254 0.5576 0.6897 1.9522 1578 2831 254 0.5785 0.6068 1.7176 1'101 1881 254 0.6005 0.5472 1.5489 765 930 254 0.6181 0.4999 1.4150 483 30 254 0.6491 0.3533 1.0872 25 15 60 0.8534 , I 0.3521 1 .0000 0 Prepared for BP-Alaska 1/14/2002 PF-02-002 Page 15 ') ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 13 BP Exploration Alaska, Northstar Well NS..31, Ivishak Combined Sample: 1.06 -1.10, Gas Properties from Differential liberation at 254°F, Sample Depth: 11.224 ft. Pressure Gas Density Gas Gravity Evo!. GOR (Psia) at the Pressure Stage (Air=1) (SCF/STB) Z Factor * (glee;) 3781 0.29030 0.8745 1398 0.7904 2831 0.17854 0.8311 1875 0.7749 1881 O. 11 038 0.8247 2211 0.7888 930 0.05156 0.8752 2494 0.8704 30 0.02933 1.3813 2976 0.9960 . . Total Evolved Gas Density . (~tlcc) ** 0.001389 0.001320 0.001281 0.001261 0.001482 .11< * Meaasured Values ** Cummulative Mass Evolved I Cummutative Volume Evolved Prepared for BP-Alaska 1/14/2002 PF-02-002 Page 16 WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 14 BP Exploration Alaska, Northstar Well NS-31 , Ivishak Combined Sample: , .06 - ,., 0, C36+ Recombined Composition from a Differential Liberation, Sample Depth: ".224 ft. Stage No. 1 2 3 4 5 STO Pressure (Psla) 3781 2831 1881 930 30 15 Temperature ("F) 254 254 254 254 254 104 Gas Gravity (Air = 1) · 0.8745 0.8311 0.8247 0.8752 1.3813 Avg. M.W. (gImol)·· 32.403 26.404 24.91 25.881 58.863 226.618 Component Mole % Mole % Mole % Mole % Mole % Mole % Weight % Nitrogen N2 0.034 0.794 0.019 0.000 0.003 0.000 0.000 Carbon Dioxide CO2 5.031 5.404 5.754 6.291 3.562 0.000 0.000 Methane C1 69.792 73.430 74.564 69.968 26.071 0.000 0.000 Ethane C2 6.856 7.558 8.093 9.858 9.222 0.002 0.000 Propane C3 4.297 4.506 4.778 6.241 10.102 0.007 0.001 IsoButane i--C4 0.730 0.748 0.743 0.965 2.579 0.009 0.002 Normal Butane n-C4 1.713 1.716 1.695 2.201 7.081 0.043 0.011 IsoPentane j-C5 0.609 0.565 0.525 0.652 3.361 0.085 0.027 Normal Pentane n--C5 0.794 0.711 0.648 0.793 4.652 0.164 0.052 Hexanes C6 1.041 0.788 0.659 0.730 6.946 0.834 0.309 Benzene C6H6 0.077 0.053 0.043 0.049 0.619 0.153 0.053 Heptanes C7 1.615 0.981 0.747 0.791 9.555 3.076 1.303 Toluene C7H8 0.189 0.089 0.062 0.060 1.053 0.734 0.298 Octanes CB 2.002 0.934 0.635 0.612 8.354 6.654 3.142 Nonanes C9 1. 608 0.577 0.372 0.326 3.779 7.542 4.027 Decanes C10 1.200 0.351 0.219 0.167 1.707 7.936 4.693 Undecanes C11 0.775 0.205 0.129 0.088 0.692 6.925 4.492 Dodecanes C12 0.495 0.130 0.083 0.050 0.303 6.288 4.467 Tridecanes C13 0.422 0.119 0.074 0.044 0.169 6.750 5.212 Tetradecanes C14 0.249 0.080 0.045 0.027 0.076 6.023 5.050 Pentadecanes C15 0.165 0.065 0.030 0.023 0.035 5.402 4.911 Hexadecanes C16 0.103 0.051 0.019 0.018 0.018 4.412 4.322 Heptadecanes C17 0.070 0.041 0.013 0.013 0.011 3.972 4.154 Octadecanes C1B 0.052 0.033 0.011 0.010 0.010 3.792 4.200 Nonadecanes C19 0.034 0.023 0.009 0.007 0.010 3.414 3.962 Elcosanes C20 0.020 0.014 0.007 0.004 0.008 2.804 3.403 Henicosanes C21 0.012 0.010 0.005 0.003 0.007 2.406 3.090 Docosanes C22 0.007 0.007 0.004 0.002 0.004 2.175 2.927 Tricosanes C23 0.004 0.005 0.003 0.002 0.003 1.937 2.718 Tetracosanes C24 0.002 0.004 0.002 0.001 0.001 1.696 2.477 Pentacosanes C25 0.002 0.003 0.002 0.001 0.001 1.680 2.557 Hexacosanes C26 0.001 0.002 0.002 0.001 0.001 1.358 2.151 Heptacosanes C27 0.001 0.002 0.001 0.001 0.001 1.279 2.112 Octacosanes C2B 0.000 0.001 0.001 0.000 0.002 1.174 2.010 Nonacosanes C29 0.000 0.001 0.001 0.000 0.001 1.086 1.927 Triacontanes C30 0.000 0.001 0.000 0.000 0.001 0.749 1.817 Hentriacontanes C31 0.000 0.001 0.000 0.000 0.000 0.695 1.693 Dotriacontanes C32 0.000 0.000 0.000 0.000 0.000 0.626 1.526 Tritrlacontanes C33 0.000 0.000 0.000 0.000 0.000 0.595 1.449 Tetriacontanes C34 0.000 0.000 0.000 0.000 0.000 0.582 1.419 Pentatriacontanes C35 0.000 0.000 0.000 0.000 0.000 0.440 1.072 Hexatriacontanes+ C36+ 0.000 0.000 0.000 0.000 0.000 4.502 10.965 Total 100.000 100.000 100.000 100.000 100.000 100.000 100.000 . Gas Gravity (Air = 1) is Based on Gas Portion of the Sample Only .. Average Molecular Weigh1 (gImol) is Based on the Mathematically Recombined Gas and Oil Fractions Together Prepared for BP-Alaska 1/14/2002 PF-02-002 Page ') WESTPORT TECHNOLOGY CENTER INTERNATIONAL ) TABLE 15 BP Exploration Alaska, Northstar Well NS-31, Ivishak Combined Sample: 1.06 -1.10, Multistage Separation Study Summary, Sample Depth: 11.224 ft. . þ,ressure (psia)' Temperature eiF). GOR (SCF1STB) on Density (g/cc)^· Gas Gravity (Air =1) Separator Voilume' \ Total GOR Formation Volume Factor** API Spent Oil 765.71 160 1818.7564 0.7850 0.7626 1 ,9790 2135.9221 2.292 42.1190 ^Oil Densities at Separator Conditions ** Based On Reservoir Pressure 4732 Psia and 254°F Prepared for BP-Alaska 1/14/2002 340..05 157 193.3203 0.8014 0.8518 1.1333 85.25 164 121.5838 0.8212 1.3293 1.0831 69.26 79 2.2615 0.8315 1..1282 1.01,34 . \ï.H SCF/STB Res. Bbls I STB 2.4616 PF-02-002 Page 18 WESTPORT TECHNOLOGY CEN fER INTERNATIONAL TABLE 16 BP Exploration Alaska, Northstar Well NS-31, Ivishak Combined Sample: 1.06 - 1.10, Gas Properties from Separation Study, Sample Depth: 11.224 ft. Pressure (Psia) 765.71 340.05 85.25 69.26 Temperature (OF) 160 157 164 79 Gas Gravity (Air=1) 0.7626 0.8518 1.3293 1 .1282 Components Mole % Mole % Mole % Mole % Nitrogen N2 0.803 0.242 0.146 0.001 Carbon Dioxide CO2 5.719 6.906 5.925 7.146 Methane C1 77.455 68.520 33.053 43.922 Ethane C2 8.037 11 .544 17.998 18.660 Propane C3 4.447 7.391 19.788 16.766 Isobutane -C4 0.640 1.013 3.854 2.567 Normal Butane N-C4 1.314 2.087 8.613 5.411 Isopentane I-C5 0.334 0.505 2.407 1 .298 Normal Pentane N-C5 0.382 0.574 2.754 1 .445 Hexanes C6 0.290 0.414 2.067 0.965 Benzene C6H6 0.018 0.026 0.129 0.064 Heptanes C7 0.260 0.352 1.726 0.791 Toluene C7H8 0.017 0.023 0.101 0.110 Octanes C8 0.165 0.211 0.967 0.458 Nonanes C9 0.071 0.093 0.329 0.182 Decanes C10 0.028 0.050 0.096 0.092 Undecanes C11 0.011 0.028 0.030 0.071 Docecanes C12 0.003 0.010 0.009 0.021 Tricanes Plus C13+ 0.003 0.010 0.007 0.030 Total 100.000 100.000 100.000 100.000 Prepared for BP-Alaska 1/14/2002 PF-02-002 Page 19 ) ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 17 BP Exploration Alaska, Northstar Well NS-31, Ivishak Combined Sample: 1.06 - 1.10, STO Properties from Separation Study at 60o/15Psia, Sample Depth: 11.224 ft. Compound Weight % Mole % M.W. (gImol) C2 0.00 0.000 30.070 C3 0.537 2.085 44.097 iC4 0.364 1.073 58.123 nC4 1.207 3.555 58.123 iC5 0.957 2.271 72.150 nc5 1.415 3.357 72.150 C6 2.965 6.040 84.000 Benzene 0.239 0.524 78.120 C7 5.361 9.555 96.000 Toluene 0.059 0.111 92.150 C8 7.818 12.503 107.00 C9 5.959 8.428 121.00 C10 5.42 6.922 134.00 C11 4.449 5.179 147.00 C12 3.977 4.227 161.00 C13 4.345 4.248 175.00 C14 4.01 3.611 190.00 C15 3.783 3.142 206.00 C16 3.223 2.484 222.00 C17 3.044 2.198 237.00 C18 3.035 2.069 251.00 C19 2.834 1.844 263.00 C20 2.403 1.495 275.00 C21 2.175 1.279 291.00 C22 2.045 1.147 305.00 C23 1.892 1.018 318.00 C24 1.701 0.879 331.00 C25 1.605 0.796 345.00 C26 1 .461 0.697 359.00 C27 1.406 0.643 374.00 C28 1.339 0.590 388.00 C29 1.273 0.542 402.00 C30 1.311 0.408 416.00 C31 1.265 0.392 430.00 C32 1.163 0.361 444.00 C33 1.153 0.358 458.00 C34 1.134 0.351 472.00 C35 1.106 0.343 486.00 C36+ 10.569 3.276 668.00 Total 100.00 100.00 Avg. Mol.Weight (gImol) 171.130 Prepared for BP-Alaska 1/14/2002 PF-Q2-Q02 Page 20 )~cember 2003 AOGCC injection report for Norhstar . . n rd A£_~~ €k~l:... J C7rvU .; Hi Jim and Winton, Attached are the pressure and injection plots and pressure readings for NS-27, NS-29, and NS-31 for December 2003. Post RWO MITIAs will be performed on NS27 and NS29 and the annual NFT-IA and semi-annual MITIA on NS31 will be performed once NS27 is returned to injection in February. Notes on wells: NS27 This well was shut in November 16 for a RWO to replace the tubing. This work was completed December 3, but the well is still shut-in pending post rig slickline work that cannot be performed until February due to rig interference. During the rig operations, the IA was tested to 5800 psi after the new tubing was in place. NS29 The RWO to replace the tubing was completed in November and the well was put back on injection on November 16. No bleeds were required in December. There have been several shutdowns since this well was put back on injection and each time this well's IA pressure has dropped to 0 psi as the well has cooled off indicating that the pressure is all thermally induced. NS31 NS31's IA required zero bleeds in December. If you have any questions, please don't hesisitate to contact me. Thanks, John CUbbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 «Northstar - December 2003.xls» «NS27, NS29 and NS31 December 2003 Annular P data ~lots.ZIP» Content-Description: Northstar - December 2003.xls Northstar - December 2003.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 NS27, NS29 and NS31 December 2003 Annular P data plots.ZIP NS27, NS29 and NS31 . Content-Description: December 2003 Annular P . data plots.ZIP . Content-Type: application/x-zip-compressed . Content-Encoding: base64 1 of 1 3/11/2004 3: 15 PM . NS29 ... Injection Injection Inner Outer Pressure Injection Temperat Annulus Annulus (from Wellhead Rate (from ure (from Inner (From Outer (From HMI) Pressure HMI) HMI) Annulus HMI) Annulus HMI) Bleed Down 12/1/2003 12/1/2003 12/1/2003 12/2/2003 12/2/2003 12/3/2003 12/4/2003 12/4/2003 12/4/2003 12/4/2003 12/5/2003 12/5/2003 12/6/2003 12/6/2003 12/6/2003 1217/2003 1217/2003 1217/2003 12/8/2003 12/9/2003 12/9/2003 12/10/2003 12/10/2003 12/10/2003 12/11/2003 12/11/2003 12/11/2003 12/12/2003 12/12/2003 12/12/2003 12/13/2003 12/13/2003 12/14/2003 12/14/2003 12/15/2003 12/15/2003 12/16/2003 12/16/2003 12/16/2003 12/17/2003 12/17/2003 12/18/2003 12/18/2003 12/18/2003 12/19/2003 12/19/2003 12/19/2003 12/20/2003 12/20/2003 12/20/2003 12/21/2003 12/21/2003 12/21/2003 12/22/2003 12/22/2003 12/22/2003 12/23/2003 12/23/2003 12/23/2003 12/24/2003 12/24/2003 12/24/2003 12/25/2003 12/25/2003 12/25/2003 12/26/2003 12/26/2003 12/26/2003 12/27/2003 12/27/2003 psi 4339.6 0 0 4344.6 0 4346.9 4570.6 0 0 0 4534.5 0 4553 0 0 4566.7 0 0 5113.1 0 0 5253.9 0 0 5282.7 0 0 5438.1 0 0 5359.6 0 5361.8 0 550.7 0 5444.7 0 0 5416.4 0 5230.3 0 0 5312.3 0 0 5363.5 0 0 5382.8 0 0 5374.9 0 0 5357.7 0 0 5286.6 0 0 5233 0 0 5373 0 0 5380.4 0 psi MMSCFPD 0 0 4600 0 4550 0 0 0 4500 0 0 29164 0 0 4600 0 4530 0 4600 0 0 0 4600 0 0 0 4600 0 4600 0 0 0 4600 0 5000 0 0 0 5450 0 5250 0 0 0 5400 0 5300 0 0 0 5300 0 5450 0 0 0 5500 0 5400 0 0 0 5400 0 0 0 5400 0 0 0 54500 0 0 0 5450 0 5400 0 0 0 5200 0 0 0 5375 0 5450 0 0 0 5300 0 5550 0 0 97325 5500 0 5650 0 0 97031 5500 0 4650 0 0 92598 4950 0 5000 0 0 96710 5300 0 4850 0 0 97393 5325 0 5500 0 0 94343 5500 0 5400 0 0 100116 5550 0 5350 0 0 98959 5350 0 degF 221 0 0 221 0 220 222 0 0 0 217 0 218 0 0 218 0 0 212 0 0 212 0 0 212 0 0 221 0 0 221 0 220 0 64 0 212 0 0 212 0 212 0 0 213 0 0 215 0 0 212 0 0 217 0 0 213 0 0 211 0 0 212 0 0 212 0 0 213 0 psi 0 448 45 0 414 0 0 795 590 605 0 655 0 615 615 0 670 1067 0 1370 960 0 950 941 0 940 1340 0 1525 361 0 1575 0 1500 0 1016 0 1040 1060 0 994 0 1094 1095 0 1181 1296 0 1298 1346 0 1192 6440 0 785 1265 0 1065 1040 0 1242 1317 0 1267 1340 0 1368 1391 0 1368 psi 211 0 0 0 0 168 585 0 0 0 396 0 446 0 0 466 0 0 664 0 0 738 0 0 755 0 0 1200 0 0 1183 0 1172 0 0 0 852 0 0 851 0 810 0 0 929 0 0 1041 0 0 980 0 0 1050 0 0 1043 0 0 1009 0 0 1001 0 0 1111 0 0 1153 0 psi psi 0 0 185 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 200 200 0 190 180 0 160 180 0 175 170 0 185 190 0 185 185 0 190 190 0 190 0 0 0 0 0 0 224 0 0 0 202 0 204 0 0 206 0 0 198 0 0 197 0 0 195 0 0 243 0 0 245 0 244 0 107 0 207 0 0 205 0 200 0 0 210 0 0 222 0 0 212 0 0 215 0 0 213 0 0 208 0 0 205 0 ----- 0 211 0 0 21~1 flag . Press Start psi Press Discharge Ending Time Bleed Comp gas, diesel, psi min G&D or water . NS31 . '" Injection Injection Inner Outer Pressure Injection Temperat Annulus Annulus (from Wellhead Rate (from ure (from Inner (From Outer (From Press Press Discharge HMI) Pressure HMI) HMI) Annulus HMI) Annulus HMI) Bleed Down Start Ending Time Bleed Comp gas, diesel, psi psi MMSCFPD degF psi psi psi psi flag psi psi mln G&D or water 12/1/2003 4347.2 0 0 221 0 774 0 226 12/1/2003 0 3150 0 0 1112 0 200 0 12/1/2003 0 4800 0 0 1120 0 220 0 12/2/2003 4354.8 0 0 221 0 789 0 249 12/2/2003 0 5000 0 0 1122 0 200 0 12/3/2003 4352.9 0 0 220 0 801 0 217 12/4/2003 4602.7 0 0 72 0 679 0 0 12/4/2003 0 4600 0 0 735 0 0 0 12/4/2003 0 0 0 0 0 0 0 0 12/4/2003 0 4600 0 0 732 0 0 0 12/5/2003 4566.7 0 0 54 0 686 0 0 12/5/2003 0 0 0 0 0 0 0 0 12/6/2003 4584 0 0 54 0 731 0 0 12/6/2003 0 4600 0 0 700 0 0 0 12/6/2003 0 0 0 0 0 0 0 0 1217/2003 4597 0 0 52 0 787 0 0 1217/2003 0 4600 0 0 850 0 0 0 1217/2003 0 5100 0 0 883 0 0 0 12/8/2003 5183 0 0 48 0 849 0 0 12/9/2003 0 5000 0 0 1795 0 425 0 12/9/2003 0 5000 0 0 1520 0 215 0 12/10/2003 4896.4 0 0 212 0 1521 0 195 12/10/2003 0 5000 0 0 1735 0 200 0 12/10/2003 0 5000 0 0 1760 0 230 0 12/11/2003 5286.1 0 0 211 0 1552 0 313 12/11/2003 0 5400 0 0 1760 0 340 0 12/11/2003 0 5400 0 0 1820 0 600 0 12/12/2003 - 5437.5 0 0 221 0 1635 0 644 12/12/2003 0 5500 0 0 1875 0 700 0 12/12/2003 0 5400 0 0 1875 0 700 0 12/13/2003 5357.8 0 0 221 0 1637 0 587 12/13/2003 0 5450 0 0 1900 0 700 0 12/14/2003 5359.8 0 0 219 0 1650 0 520 12/14/2003 0 5400 0 0 1900 0 560 0 12/15/2003 726.8 0 0 77 0 51 0 0 12/15/2003 0 5400 0 0 262 0 175 0 12/16/2003 5439.2 0 0 212 0 819 0 258 12/16/2003 0 5400 0 0 1185 0 285 0 12/16/2003 0 5400 0 0 1435 0 350 0 12/1712003 5410.7 0 0 212 0 1351 0 359 12/17/2003 0 5200 0 0 1716 0 115 0 12/18/2003 5230.5 0 0 212 0 1406 0 165 12/18/2003 0 5300 0 0 1737 0 185 0 12/18/2003 0 5300 0 0 1768 0 220 0 12/19/2003 5305.5 0 0 213 0 1424 0 270 12/19/2003 0 5325 0 0 1516 0 260 0 12/19/2003 0 5350 0 0 1421 0 320 0 12/20/2003 5356 0 116505 215 0 1094 0 347 12/20/2003 0 5375 0 0 1320 0 325 0 12/20/2003 0 5400 0 0 1071 0 340 0 12/21/2003 5374.8 0 116036 212 0 615 0 271 12/21/2003 0 5325 0 0 1241 0 240 0 12/21/2003 0 5700 0 0 1293 0 220 0 12/22/2003 5367.4 0 106842 216 0 1047 0 285 12/22/2003 0 4850 0 0 1606 0 0 0 12/22/2003 0 5650 0 0 6490 0 240 0 12/23/2003 5352.1 0 111425 213 0 828 0 298 12/23/2003 0 5375 0 0 985 0 215 0 12/23/2003 0 4900 0 0 890 0 240 0 12/24/2003 5283 0 112862 211 0 587 0 244 12/24/2003 0 5800 0 0 890 0 240 0 12/24/2003 0 5400 0 0 1293 0 270 0 12/25/2003 5234.2 0 108237 212 0 912 0 238 12/25/2003 0 5350 0 0 1065 0 240 -_0. ---~~ 12/25/2003 0 5650 0 0 842 0 660 0 12/26/2003 5366.8 0 117594 212 0 469 0 302 12/26/2003 0 5500 0 0 743 0 290 0 12/26/2003 0 5380 0 0 668 0 290 0 12/27/2003 5373 0 117482 213 0 280 0 327 12/27/2003 0 5380 0 0 1169 0 285 0 t. December 2003 IA Pressure Data NS27, NS29 and NS31 NS27 This well was shut in November 16 for a RWO to replace the tubing. This work was completed December 3, but the well is still shut-in pending post rig slickline work that cannot be performed until February due to rig interference. During the rig operations, the IA was tested to 5800 psi after the new tubing was in place. NS29 4IÞ The RWO to replace the tubing was completed in November and the well was put back on injection on November 16. No bleeds were required in December. There have been several shutdowns since this well was put back on injection and each time this well's IA pressure has dropped to 0 psi as the well has cooled off indicating that the pressure is all thermally induced. NS31 NS31 's IA required zero bleeds in December. 8 ~ Ø) N en Z ~ :J "ê Q) a. E Q) l- e 0 ~ Q) 'c CI a.. U C/) ~ ~ Q) +" ro a:: e 0 ~ Q) 'c "0 Q) Q) CO . ::!; I ~ :J (f (f ~ a. « I ~ :J en en Q) ~ a.. e 0 ~ () Q) '-' e . . 1.0 I'-- C\I L() C\I C\I ~unt"uadwa.l pue ate~ uo!t:>afu 0 L() 0 L() 0 0 I'-- 1.0 C\I 0 C\I ...... ...... ...... ...... L() C\I 0 0 C"') 0 L() C\I a r < " ~ ~ ; '--------- - \~ (~ l 4...~ '~;- I' ' !!a- ~ :. t(- I .. , c :il ~ \ 'L- L- r f -5 {=- '\. ,["T .1- 7:- ~-1- ~ r ~ 0 0 0 (0 0 0 1.0 L() 0 0 0 L() 0 0 L() ~ 0 0 0 ~ 0 0 1.0 C"') 0 0 0 ('f) aJnssaJd ~~ .. .. ,- £OOZ/S ~M 0 0 0 1.0 L() I'-- 0 1.0 r~ .1 ï ~ ... .. . . '.. F- {- ~ ( \ ~- -! ! .} t -~ ~ r ~ ~ ~ rl ~L ~t t / - J } ~ 1 .c; -J=; ~ ~ 2. ~.. 0 0 L() C\I 0 0 0 ...... 0 0 0 C\I 0 0 L() ...... 0 £OOZI LUG ~ £OOG/OG/Z ~ £OOZI£ ~/Z ~ £OOZ/9/Z ~ £OOZ/6Z/~ ~ . £OOZIZZI ~ ~ 6000 5500 5000 4500 4000 3500 f ::I ~ 3000 ( ) ... D.. 2500 2000 1500 NS31 I-Injection Pressure -IA Pressure. Bleed Flag -Injection Rate, MMSCFPD -Injection Temperature I .-.~-_._- nP -- r ~ rl ~ 1"'1, ......, ~ ...,I,~ ~r'tA ";' ~, ~ ~ ~ r~ 1000 ~....fI- 'I " 500 /' t,. o-~' CV) 0 0 ~ I.!) T"" -.. T"" T"" CV) 0 0 N -.. N ~ T"" T"" CV) 0 0 N - 0> ~ T"" T"" t\., -_.--- ,. ----,,-----.-- 300 . "-1" 275 /~ v" (fl1 ~ r ~\r 1- ---^-~r~ìr~ ~ ,-- ..A Frozen sensing line ~-~. :I":"':~.:'~ ~1 ,- r -- I '~ CV) 0 0 ~ co - N T"" CV) 0 0 N - 0 N - N T"" CV) 0 0 ~ I'-- ~ N T"" -'-."r- ) L~' r ~\ IÎf~"J1.-L~ I ,\", \J \ ~~ -----Y' ",.t,lt_."" ,A""J"-,,,, , CV) 0 0 ~ CV) T"" - N T"" 250 225. ( ) ... 200.a ca ... ( ) c. 175 E ( ) I- "C 150 ¡ ( ) - ca 125 ~ c 0 ~ 1 00 .!. ~ . 75 50 25 0 ~ ,~ ~' /7/7 / /1 I; ()' /-' L/ . V ß~ North",.1ar July 2003 Injector Readings Subject: Northstar July 2003 Injector Readings Date: Sun, 3 Aug 2003 16:55:47 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> To: "AOGCC Tom Maunder (E-mail)" <Tom_Maunder@admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <Winton_Aubert@admin.state.ak.us>, "AOGCC Jim Regg (E-mail)" <Jim_Regg@admin.state.ak.us> 5f;1/ 2-1/L{ \03- CC: "Francis, Michael J" <Michae1.Francis@BP.com>, ~h ,.;( . "PBU, Nstar Lead Tech" <PBUNstarLeadTech@BP.com>, 11..c'-' 7 (t(Þ'-¡ "PBU, Nstar Operations Manager" <PBUNstarOperationsManager@BP.com>,/ "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Hi Jim and Winton, Attached are the pressure and injection plots and pressure readings for NS-27, NS-29, and NS-31 for July 2003. Notes on wells: NS27 NS27's IA was bled down four times in July to maintain the pressure below 3000 psi. NS29 NS29's IA was bled down four times in July. It was bled three times to maintain the pressure below 3000 psi, and once to facilitate a temperature log. NS31 NS31's IA required one bleed in July to maintain the pressure below 3000 psi. If you have any questions, please don't hesisitate to call. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 «Northstar - July 2003.ZIP» data plots. ZIP» «NS27, NS29 and NS31 July 2003 Annular P r::::':::::::::~"""""""""""""""""""""""""""'"...............................................:......:............................'...............................................................................:.::::......................................................"........................................""""""""""""""""""""""""""""""""""""""""""""""""...............:..................". :""""""""""',"""......"""¡¡¡¡,.".."..,,¡,.,.,,w...,'",¡¡",¡"""""""""'""""""""""""""'",,,...,,. .."""......."",.,!o".,.....,.............."..."............",..,."""."'.,.,.",,",...,....' """o"""""""""""",'"'"O¡"""""""",,,,"'¡ Name: Northstar - July 2003.ZIP ~Northstar - July 2003.ZIP Type: Zip Compressed Data (application/x-zip-compressed) Encoding: base64 ' ."", '..' .,.¡" .,'X'¡ " ", .""""'¡¡ , , ....... ., ., ] %itANNED S E P 1 5 2003 8/4/2003 4:08 PM hlorthr, mr July 2003 Injector Readings ~__~NS27, NS29 and NS31 July 2003 Annular P data plots. ZIP Name: NS27, NS29 and NS31 July 2003 Annular P data plots.ZI! Type: Zip Compressed Data (application/x-zip-compresset Encoding: base64 2 of 2 8/4/2003 4:08 PM July 2003 IA Pressure Data NS27, NS29 and NS31 NS27 NS27's IA was bled down four times in July to maintain the pressure below 3000 psi. NS29 NS29's IA was bled down four times in July. It was bled three times to maintain the pressure below 3000 psi, and once to facilitate a temperature log. NS31 NS31's IA required one bleed in July to maintain the pressure below 3000 psi. Injection Pressure 'NS27 --IA Pressure · IA Bleed Flag --Injection Rate, MMSCPD ~ Injection Temperature 6000 55OO .................... 300 275 5OOO 45O0 4000 3500 3000 2500 2000 1500 250 225 2OO 175 150 125 100 75 1000 50 5OO 25 o o o o o 6000 5500 5000 45OO 4000 3500 3000 2500 2OOO 1500 1000 500 --Injection Pressure NS29 IA Pressure IA · Bleed --Injection Rate, MMSCPD Injection TemperatureI (:::) (::) O (:~ (:~ (2) (:::) 300 275 250 225 200 ~ 175 E 150 c 125 ~ O 100 .e_., 75 5O 25 'NS31 6O0O 55OO Injection Pressure IA Pressure · Bleed Flag Injection Rate, MMSCFPD -- Injection Temperature 30O 275 5OO0 4500 4OOO 35OO 3000 2500 2OOO 1500 250 225 200 175 150 125 100 75 1000 50 5OO 25 o o o o o o 00 o o 0 o 0 o o o c',,,I bp Michael J. Francis, P.E. Senior Petroleum Engineer Northstar BP ExpLoration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 6/12~2O03 Winton Aubert Jim Regg Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue Suite100 Anchorage, Alaska, 99501-3539 Phone: (907) 564-4240 Fax: (907) 564-5200 Email MichaeI.Francis@bp.com Web: www.bp.com RE: NS31 Sundry Approval Requests Gentlemen' BP Exploration (Alaska) Inc. seeks sundry approval to allow for the continuing operation of the NS31 gas injection well. This well exhibits signs of very minor tubing by inner annulus communication. The current AOGCC authorization to inject gas into this well is good through June 30, 2003. An Application for Sundry Approval Form, Description Summary of Proposal document and a performance plot for the subject well are enclosed. Please call if you have any questions or would like to discuss. Sincerely, Michael J. Senior Petroleum Engineer Attachments CC: RECEIVED 2.003 Tom Gray John Garing Joe Anders/John Cubbon John Smart/Gary McB.ri~ R i G 1N A L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance X Perforate _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1348' FSL, 649' FEL, Sec. 11, T13N, R13E, UM At top of productive interval 1995' FSL, 5090' FEL, SEC 12, T13N, R13E, UM At effective depth 2026' FSL, 219' FWL, Sec. 12, T13N, R13E, UM At total depth 2034' FSL, 5046' FEL, Sec 12 T13N, R13E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service_X (asp's 659822, 6031120) (asp's 660646, 6031785) (asp's 660675, 6031817) (asp's 660684, 6031825) 6. Datum elevation (DF or KB feet) RKB 56.0 feet 7. Unit or Property name Northstar Unit 8. Well number NS31 9. Permit number / approval number 201-060-0 10. APl number 50-029-23009 11. Field / Pool Northstar Unit 12. Present well condition summary Total depth: measured 11440 feet Plugs (measured) true vertical 11280 feet Effective depth: measured 11356 feet Junk (measured) true vertical 11197 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 199' 20" Driven 244' 244' Surface 3192' 13-3/8" 1534 sx PFE, 470 sx 'G' 3237' 3234' Intermediate 10882' 9-5/8" 530 sx Econolite 'G', 977 10927' 10774' sx Class 'G' Liner 658' 7" 190 sx Class 'G' 10781' - 11439' 10631' - 11280' Perforation depth: measured Open Peffs 11150'-11170', 11184'- 11304' RECEIVED true vertical Open Peris 10994'-11014', 11027'-11146' JUN ! 3 2003 Tubing (size, grade, and measured depth 7", 29#, 13Cr TBG @ 10730' MD. Tubing Tail @ 1o78~laska 0il & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) 9-5/8" x 7" BAKER SABL-3 Packer @ 10730'. 7" HRQ SSSV @ 2037' MD. 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation July 1, 2003 16. If proposal was verbally approved Name of approver Date approved Oil _ Gas _ Service GAS INJECTION Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ . &"2 Title: Senior Petroleum Engineer Michael~J. Francis, P.E~ ~...._~ FOR COMMISSION USE ONLY Questions? Call Joe Anders / Kevin Yeager, (907) 659 - 5102. Date June 11,2003 Prepared b~/DeWar/ne R. Schnorr 564-5174 Conditions of approval: Notify Commission so representative may witness Approval no. Plug integrity_ BOP Test_ Location clearance __ . . . Mechanical Integrity Test_ Subseq~Lent form required 10- j App r o v/'e~bjgy orY~d~ o~he CP-~o~'''c~mission't'ES ~ J~O~ i"Z.,-O~-,~.._~..-' ~1~ '~~.A" jCo~mmissioner Date Form 10-403 Rev 06/15/88. ' -- '~t},~1~3~;I!~ ' ~'~1~,,~ l-- ~.~.~ TRIPLICATE NS31 Description Summary of Proposal 06/11/03 Problem: Gas Injector with slow IA re-pressurization Well History and Status Well NS31 (PTD 2010600) is an injector that exhibits very slow IA re-pressurization. An extremely small connection or packer internal seal leak is suspected. Less than one bleed per month is required to keep the IA pressure under 3000 psi. A plot showing the last six months of IA pressure data plotted along with injection pressure, temperature and rate is attached. A Summary of relevant events is shown below: · 12/02/01: Started injection service · 12/08/01: MIT IA passed (2700 psi) while well on injection · 12/14/02: Tubing by inner annulus (IA) communication detected · 2/23/2002:1A FL at 275' · 6/23/2002: IA FL @ 850' · 08/12/02: IA FL @ 850' · 11/17/02: IA FL @ 740' · 01/02/03: NFT-IA Passed*, IA FL @ 990' · 02/19/03: IA FL @ 780' · 04/13/03: IA FL @ 895' · 05/01/03: IA FL @ 870' *note - The no flow test (NFT~IA) conducted on 01/02/03 yielded a final gas rate of 210 scf/hour. While this value is well below the 900 $CF/Hour APl 14C $SV allowable leak rate criteria, the test appears to have been terminated before the well reached its true (much lower) leak rate. The actual leak rate is befieved to be less than 10 $CF/hour. This agrees with the rates calculated from pressure increase trends. This sundry request is to allow for continued injection of gas. A long-term waiver is sought due to the small magnitude of the communication. BP would like to be positioned to operate this well long term (i.e. after the rig is demobilized) in its current condition. The following supports the request: A MITIA passed on 12/08/01 to 2700 psi, demonstrating competent production casing. The estimated Gas leak rate of < 10 SCF/Hour is << 900 SCF/Hour, much less than both the 14C leak rate for SSV's and the No-Flow test criteria. Pressures, temperature and injection rate will be monitored and recorded daily. An annual IA leak rate test will be conducted to monitor the leak severity. An MITIA will be conducted every 4 years to confirm casing integrity. The Production Casing pressure rating > injection pressure. Proposed Action Plan 1. Allow well to continue long-term gas injection in its current condition. The waiver term would be open ended. 2. Limit the maximum IA pressure to 3000 psi. 3. Record wellhead pressures, temperature and injection rates daily. Also, record IA bleeds. 4. Submit a monthly report of daily pressures, temperatures and injection rate. 5. Perform an IA fluid level once a quarter. 6. Perform an IA leak rate test once a year. 7. Perform an MITIA once every 2 years. NS31 Injection Pressure ~lA Pressure ¢ Bleed Flag Injection Rate, MMSCFPD, -- Injection Temperature 600o 5500 5OOO 45OO 4OOO 35OO 3000 2500 2000 1500 t000 5OO Permit to Drill 2010600 MD 11440 '-~ TVD DATA SUBMITTAL COMPLIANCE REPORT 61412003 Well Name/No. NORTHSTAR UNIT NS-31 Operator BP EXPLORATION (ALASKA) INC 11280 ~ Completion Dat 6/2/2001.---- Completion Statu 1-OIL Current Status WAGIN APl No. 50-029-23009-00-00 UlC Y REQUIRED INFORMATION Mud Log No Sample N._~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type ~ Fmt Log Log Run Name Scale Media No (data taken from Logs Portion of Master Well Data Maint) Interval OH I Dataset Start Stop CH Received Number Comments ~ PERF (~ ~ ~(3~ 5 YDirectional Survey ~-ctional Survey ~onic Imager End of Well Report ~.MudLog /:GOO 5 /~/~ ~,~Mud Log ! ~/L~-.~: 1 t~VI~ ~Mud Log ! ~ ~ B ~ 2 ~Mud Log ~', ~-?~ 1 ~ ~ Best DT 2 ~f Well Repo~ 0 11278 Open 7/11/2001 ~1t3232 0-11278 198 10945 Open 7/26/2001 ~-'~5 198-10945 980 11460 Open 7/11/2001 O,9-189 980-11460 FINAL 10552 10834 CH 6/12/2001 10552-10834 BL, Sepia FINAL OH 6/12/2001 Directional Survey, Digital Data FINAL 0 11440 OH 6/12/2001 0-11440 Directional Survey, Paper Copy FINAL 10950. 11300 CH 6/22/2001 10950-11300 BL FINAL 5980 10836 CH 6/22/2001 5980-10836 BL, Sepia FINAL CH 6/22/2001 End of Well Report, Paper Copy FINAL 199 11440 OH 6/27/2001 199-11440 BL, Sepia FINAL 199 11440 OH 6/27/2001 199-11440 BL, Sepia FINAL 199 11440 OH 6/27/2001 199-11440 BL, Sepia FINAL 199 11440 OH 6/27/2001 199-11440 BI, Sepia FINAL 8450 11450 CH 6/27/2001 8450-11450 BL, Sepia FINAL CH 6/27/2001 End of Well Report, Paper Copy ...t_WD Sonic 2 FINAL 6800 10800 CH 7/9/2001 6800-10800 Color Print ....... ---19203 .............................................. FINAL-~- ........ -~98-. ..... .~1,09.45._~_O.L-I_ ....... -7/26/2001----10203-- 198'-10945;-Digital-Data ~'T-~'~-~. ~1.e232 FINAL 0 11278 oh 7/11/2001 ~:..1.0232 0-11278 Digital Data'~,. /V~,?~D CDR 2/5 FINAL 170 10945 OH 7/26/2001 170-10945 BL, Sepia ~vID.AND"',~.~..~.~'~_ 2/5 FINAL 170 10945 OH 7/26/2001 170-10945 BL, Sepia Permit to Drill 2010600 DATA SUBMITTAL COMPLIANCE REPORT 6/4/2003 Well Name/No. NORTHSTAR UNIT NS-31 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-23009-00-00 M D 11440 ~,~-.- · TVD 11280 Completion Ddt 6/2/2001 /~.~od ular Dynamic Tester Completion Statu 1-OIL FINAL 11402 ~rasonic imager ~-~ ~i5~ ~.~,~% ~' FINAL End of Well Report FINAL 10964 10700 11350 Current Status WAGIN CH 7/26/2001 CH 7/26/2001 CH 7/9/2001 UIC Y 11402-10964 BL, Sepia 10700-11350BL ~)' >-~/~ii End of Well Report, Paper Copy /V~.. H~gh Resolution 2/5 FINAL Laterlog /~ ~?~ay Induction Log 2/5 FINAL ~ ~.~Dipole Shear Sonic 2/5 FINAL I,mager ~ C.,Gotnbinable Magnetic 5 FINAL Resonance ~~aatform Express/ 2/5 FINAL CNL/DEN ,,.,._.Platform Express/ 2/5 FINAL ss'rvD ,.~ 0189 FINAL ,~ Perforation Record ),,~.j~'~ ).j~ ~ ! FINAL Well Cores/Samples Information: 10953 10953 10953 10953 10953 10953 980 10700 1146O CH 11460 CH 11460 CH 11460 CH 1146O CH 1146O CH 11460 OH 11350 CH 7/11/2001 7/11/2001 7/11/2001 7/11/2001 7/11/2001 7/11/2001 7/11/2001 /---t-0'189 9/10/2001 10953-11460 BL, Sepia 10953-11460 BL, Sepia 10953-11460 BL, Sepia 10953-11460 BL, Sepia 10953-11460 BL, Sepia 10953-11460 BL, Sepia 980-11460, Digital Data 10700-11350 BL, Sepia Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y(~ Chips Received? ~ Daily History Received? Formation Tops Analysis Compliance Reviewed By: Date: Michael J. Francis, P.E. Senior Petroleum Engineer Northstar BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 30, 2003 Winton Aubert Jim Regg Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue Suite100 Anchorage, Alaska, 99501-3539 RE: NS27, NS29 and NS31 Work Plan Phone: (907) 564-4240 Fax: (907) 564-5200 Email Michael. Francis@bp.corn Web: www.bp.com RECEIVED k~AY. 0 ] 2003 Alaska 0il & Gas Cons. Commission Anchorage Gentlemen' Pursuant to the AOGCC's letter of April 28, BP Exploration (Alaska) Inc. submits the following work plan. NS27: BP proposes to perform a rig workover to replace the current 7", 29#/ft, 13Cr-80 tubing with NSCC connections with 7", 32#/ft, T-95 tubing with Vam Top HC connections. Materials to perform this work have been purchased and staged on Northstar Island. This workover will be completed by August 1, 2003. NS29: BP proposes to perform a rig workover to replace the current 7", 29#/ft, L-80 tubing with NSCC connections with 7", 32#/ft, T-95 tubing with Vam Top. HC connections. Materials to perform this work have been purchased and staged on Northstar Island. This workover will be completed by August 1, 2003. NS31: BP proposes to continue to operate NS31 long term with its current tubulars. This injector exhibits very slow IA re-pressurization. The subject well has required leSs than one bleed per month for the last year and bleed frequency has not increased. The calculated leak rate is less than 10 SCF/hour, much less than the APl 14C SSV allowable leak rate of 900 SCF/hour. NS31, like all Northstar Gas Injection wells, is equipped with pressure transducers on the Inner Annulus (IA) and Outer Annulus (gA) that allow constant monitoring of these pressures in the Northstar control room. Additionally, all Northstar wells are physically checked twice daily. NS27, NS29 and NS31 Work Plan April 30, 2003-04-30 Page 2 of 3 Please call if you have any questions or would like to discuss. Sincerely, , Fra,~c~s~, - MicBael J. Senior Petroleum Engineer cc: Thomas Gray Mikel Schultz John Garing Krissell Crandall Joe Anders/John Cubbon, PBOC John Smart/Gary McBride, PBOC File L.f""t~ ~KA OIL AND GAS CONSERVATION COMMISSION o FRANK H. IVIURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael J. Francis, P.E. BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO Box 196612 Anchorage, Alaska 99519-6612 April 28, 2003 Re: Request for variance to continue gas injection in wells NS 27, NS 29, and NS 31. Dear Mr. Francis: Please reference the Alaska Oil and Gas Conservation Commission's ("AOGCC" or "Commission") November 15, 2002 letter authorizing BPXA ("BP") to continue injecting gas in wells NS 27, NS 29, and NS 31 until April 30, 2003. The Com- mission's authorization to operate these wells through April 2003 followed earlier authorizations dated February 19, 2002, and October 31, 2002 (via email), and was conditioned on BPXA providing "specific plans and a timeline for repairs in NS 29." When AOGCC authorized continued gas injection, annular communica- tion in NS 27 and NS 31 was not as severe as in NS 29. Since then, however, NS 27 appears to have become increasingly problematic, requiring frequent pressure bleeds. BPXA's Drilling Schedule has included rig workovers for wells NS 27 and NS 29 since December 2002, work to be completed just prior to the seasonal drilling shut down that begins July 1. BPXA's installation of tubing with Vam Top HC connections in NS 17 appears to have resulted in effective pressure isolation (based on early performance reported to the Commission). Michael Francis April 28, 2003 Page 2 of 2 Continued operation of Northstar gas injection wells with significant pressure communication creates appreciable and unnecessary safety risks. Accordingly, AOGCC requests that corrective action be taken on NS 27, NS 29, and NS 31. This corrective action should be completed before the seasonal drilling rig shut- down beginning July 1, 2003. If corrective action is not taken on NS 27, NS 29, and NS 31 before July 1, 2003, gas injection shall be suspended and the wells secured. Please submit to the Commission by May ,5, 2003 a definitive work plan and firm schedule for corrective action on NS 27, NS 29, and NS 31. Should you have any questions, please contact Winton Aubert at 793-1231. Sarah Palin 'v Chair Randy Ruedrich Commissioner WA:\SP\jjc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance X Perforate _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchoracje, AK 99519-6612 4. Location of well at surface 1348' FSL, 649' FEL, Sec. 11, T13N, R13E, UM At top of productive interval 1995' FSL, 5090' FEL, SEC 12, T13N, R13E, UM At effective depth 2026' FSL, 219' FWL, Sec. 12, T13N, R13E, UM At total depth 2034' FSL, 5046' FEL, Sec 12 T13N, R13E, UM 5. Type of Well: Development _ Exploratory __ Stratigraphic _ Service__X (asp's 659822, 6031120) (asp's 660646, 6031785) (asp's 660675, 6031817) (asp's 660684, 6031825) 6. Datum elevation (DF or KB feet) RKB 56.0 feet 7. Unit or Property name Northstar Unit 8. Well number NS31 9. Permit number / approval number 201-060-0 10. APl number 50-029-23009 11. Field / Pool Northstar Unit 12. Present well condition summary Total depth: measured 11440 feet Plugs (measured) true vertical 11280 feet Effective depth: measured 11356 feet Junk (measured) true vertical 11197 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 199' 20" Driven 244' 244' Surface 3192' 13-3/8" 1534 sx PFE, 470 sx 'G' 3237' 3234' Intermediate 10882' 9-5/8" 530 sx Econolite 'G', 977 10927' 10774' sx Class 'G' Liner 658' 7" 190 sx Class 'G' 10781' - 11439' 10631' - 11280' Perforation depth: measured open Perfs 11150'-11170', 11184'-11304' RECEit/ D''': true vertical Open Perfs 10994'- 11014', 11027'- 11146' APR 2 5 2003 Alaska Oil & Gas Cons. Commission Tubing (size, grade, and measured depth 7", 29#, 13Cr TBG @ 10730' MD. Tubing Tail @ 10785' AnChorage Packers & SSSV (type & measured depth) 9-5/8" x 7" BAKER SABL-3 Packer @ 10730'. 7" HRQ SSSV @ 2037' MD. 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch _ 15. Status of well classification as: 14. Estimated date for commencing operation May 1,2003 16. If proposal was verbally approved Name of approver Date approved Oil ~ Gas _ Suspended Service GAS INJECTION 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .... , j?.~ , Title: Senior Petroleum Engineer Michael ~..~rancis, P.E. // '~"'7' ~ ~/c~r¢4''2' '~ -- (/ 'J FOR COMMISSION USE ONLY Conditions of approval: N~tify Commission so representative may witness Questions? Call Joe Anders / John Cubbon, (907) 659 - 5102. Date April 18, 2003 Prepared b~, DeWayne R. Schnorr 564-5174 Plug integrity __ BOP Test __ Mechanical Integrity Test _ Approved by order of the Commission RBDMS BFL Form 10-403 Rev 06/15/88 · Location clearance _ Subsequent form required 10- ~ ~ Commissioner 2003 "'. ' Approval no. Date SUBMIT IN TRIPLICATE NS31 Description Summary of Proposal 04/18/03 Problem: Gas Injector with slow IA re-pressurization Well History and Status Well NS31 (PTD 2010600)is an injector that exhibits very slow IA re-pressurization. An extremely small connection leak is suspected. Less than one bleed per month is required to keep the IA pressure under 3000 psi. A plot showing the last six months of IA pressure data plotted along with injection pressure, temperature and rate is attached. A Summary of relevant events is shown below: · 12/02/01: Started injection service · 12/08/01: MIT IA passed (2700 psi) while well on injection · 12/14/02: Tubing by inner annulus (IA) communication detected · 2/23/2002:1A FL at 275' · 6/23~2002: IA FL @ 850' · 08/12/02: IA FL @ 850' · 11/17/02: IA FL @ 740' · 01/02/03: NFT-IA Passed*, IA FL @ 990' · 02/19/03: IA FL @ 780' *note - The no flow test (NFT-IA) conducted on 01/02/03 yielded a final gas rate of 210 scf/hour. While this value is well below the 900 SCF/Hour APl 14C SSV allowable leak rate criteria, the test appears to have been terminated before the well reached its true (much lower) leak rate. The actual leak rate is believed to be less than 10 SCF/hour. This agrees with the rates calculated from pressure increase trends. This sundry request is to allow for continued injection of gas. A long-term waiver is sought due to the small magnitude of the communication. BP would like to be positioned to operate this well long term (i.e. after the rig is demobilized) in its current condition. The following supports the request: A MITIA passed on 12/08/01 to 2700 psi, demonstrating competent production casing. The estimated Gas leak rate of < 10 SCF/Hour is << 900 SCF/Hour, much less than both the 14C leak rate for SSV's and the No-Flow test criteria. Pressures, temperature and injection rate will be monitored and recorded daily. An annual IA leak rate test will be conducted to monitor the leak severity. An MITIA will be conducted every 4 years to confirm casing integrity. The Production Casing pressure rating > injection pressure. Proposed Action Plan 1. Allow well to continue long-term gas injection in its current condition. 2. Limit the maximum IA pressure to 3000 psi. 3. Record wellhead pressures, temperature and injection rates daily. Also, record IA bleeds. 4. Submit a monthly report of daily pressures, temperatures and injection rate. 5. Perform an IA fluid level once a quarter. 6. Perform an IA leak rate test once a year. 7. Perform an MITIA once every 2 years. 6000 5500 5000 4500 4000 3500 3000 NS31 Injection Pressure '~-IA Pressure ~ Bleed Fla9 Iniection Rate! MMSCFPD ~---~-Injection Temperature 2500 2000 1500 IOO0 5OO 0 o o ~o g o o o© o o o© o© o© o TREE: ABB-VGI 7" 6.5 ksi WELLHEAD:ABB-VGI 13-5/8" 6.5 ksi Multibowl NS31 13 3/8", 68#/ft, L-80, BTC @3237' 7", 29#/ft, 13Cr, NSCC TUBING ID: 6.184" CAPACITY: 0.037 BBL/FT 7" R NIPPLE, @10709' 5.963" ID (OTIS) 7" R NIPPLE, @ 10755' 5.963" ID (OTIS) 7" RN NIPPLE, @10767' 5.77" ID (OTIS) 7" WLEG, @10785' 6.184" ID (OTIS) 9 5/8", 53.5#/ft L-80, BTC-M @10927' F~L.C~ ~rr(~) F~-h Lcc~ AN2.EATTCPI:13~. i-~ F~rf - (3-a~ 4E5 ~r,J~, HV~ Rme~a~ 54"; PBTD @11356' MD 11195' TVD TD @ 11439' DATE 6/4/01 7/24/01 REV. BY AGK EMF 9/10/01 EMF I 11/20/01 ! 12/27/02 EMF EMF COMMENTS Initial Diaqram Add Perf Inserted TVD Depths Add Perf , ,,Updated KB & S, afety ,!,n, fo (B. ELEV = 56' KB-BF. ELEV = 40.6' BASE FLANGE ELEV = 15.4' SSSV @2037' MD 2034' TVD 7" HRQ SVLN 5.963" ID ~,6.8PPG DIESEL FREEZE PROTECTION AT +/- 2700 SAFETY NOTES: SLOW TUBING x IA COMM Operating Pressure of the 9 5/8" Annulus MUST NOT Exceed 3000 psi (11-21-02 Waiver) Baker SABL-3 PACKER 6.00" ID @10730' MD 10579' TVD 7" LINERTOP (~10781' MD 10629' 'I-VD 6.184" ID 7",29#,13Cr Northstar WELL.' NS31 APl NO:50-029-23009-00 BP Exploration (Alaska) II III I I bp Michael J. Francis, P.E. Senior Petroleum Engineer Northstar BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 9, 2003 Winton Aubert Jim Regg Alaska Oil and Gas Conservation Commission 333 W. 7th AvenUe Suite100 Anchorage, Alaska, 99501-3539 RE' NS17 Performance Evaluation Gentlemen: Phone: (907) 564-4240 Fax: (907) 564-5200 Ernail MichaeI.Francis@bp.com Web: www.bp.com RECEIVED APR I 6 2003 Alaska Oil & Gas Cons. Commission Anchorage On November 15, 2002 the AOGCC authorized BP Exploration (Alaska)Inc. to continue gas injection into the NS27, NS29 and NS31 wells. The inner annuli (IA) of these :wells have exhibited pressure increases that appear 'to be .the'result of some loss of integrity of the 7" tubing. One of the conditions of this authorization was that "BPXA must provide a complete evaluation of the performance of the premium connections in NS17 within 30 days of initiating injection". This letter contains the subject evaluation. The NS17 gas injection well was completed using tubing with Vam Top HC connections. The NS27, NS29 and NS31 wells utilize tubing with NSCC connections. Although both Vam Top HC and NSCC are premium connections, Vam Top HC is a newer design. The NS17 completion also utilized, refined pipe handling and running procedures. Injection was initiated in NS17 on March 12. Since being put on injection, there are no indications that there is communication between the tubing and inner, annulus. The well's behaviour is graphically presented in Attachment I. This is a plot of injection rate, injection pressure, injection temperature, IA pressure and OA pressure. Since start-up, three bleeds have been necessary to relieve .pressure induced by the thermal expansion of the. annular fluids This is normal .:.ir) new well start-ups. In instances of annular pressure induced by thermal expansion, the pressure should drop to zero psi when the annular fluids cool down. This response can be seen on several occasions when the rate (black line) drops to zero, the wellhead temperature (red line) begins to fall and the IA pressure (pink line) drops to zero psi. A mechanical integrity test of the IA (MITIA) was performed on April 4, 2003. The NS17 passed this test that was witnessed by Chuck Scheve of the AOGCC. Please call if you have any questions or would like to discuss. Sincerely, ~~eer Attachment cc: Mikel Schultz John Garing Jeff Walker, MMS WIE, PBOC File Attachment I - NS17 Injection Rate, Pressure, Temperature, IA pressure and OA pressure Injection Pressure IA Pressure e Bleed Flag ~OA Injection Temperature --Calculated Inj Q, MMSCFPD ] 60OO 550O 5OOO 45OO 40OO 35OO 3000 25OO 2000 1500 IOO0 5OO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CD 0 CD 0 0 o o o o o o o o o o o o o o o o o o o o o o o o o o o o o 3OO 275 25O 225 '~-- 200 175 E 150 125 100 'E' 75 50 25 .N,~rth2tar~Piots 12-02 Subject: Northstar Plots 12-02 Date: Mon, 6 Jan 2003 12:43:34 -0600 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegfityEngineer@BP.com> To: Jim Regg <jim_regg~admin.state.ak.us> CC: "- Winton Aubert (E-mail) ' 'AOGCC (E-mail)" <Winton_Aubert@admin.state.ak.us>, "AOGCC Tom Maunder (E-mail)" <Tom_Maunder~admin.state.ak.us> Hi Jim. I'll send you 2 emails with the problem attachments not compressed. Let me know if it still has problems. Joe ..... Original Message ..... From: Jim Regg [mailto:jim regg@admin.state.ak.us] Sent: Monday, January 06, 2003 9:31 AM To: NSU, ADW Well Integrity Engineer Cc: Tom Maunder Subject: Re: Northstar December Injector Readings pressure plots and NS31 reading are not readable; would appreciate it if you resend just those files. Thanks. Jim Regg "NSU, ADW Well Integrity Engineer" wrote: > Hello Tom. > Attached are pressure/production plots and pressure readings for NS27, NS29 > & NS 31 for December 2002. Notes on the wells: > > NS27's IA was bled down twice during December. The first time was to > maintain the pressure below 3000 psi. The second time was to facilitate a > rig move to the NS24 well. > > NS29's IA was bled down once in December to maintain the pressure below 3000 > psi. > > There were no NS31 IA bleeds.during December. > > I had to compress the attachments to meet the 1 meg email limit. Please > contact Mike Francis or me if you have'any questions or problems with the > files. > > Thanks! > Joe > Joe Anders, PE / John Cubbon > Well Integrity Engineer > BP Exploration, (Alaska) Inc. > (907) 659-5102 > email: NSUADWWellIntegrityEngineer@bp.com > > <<NS-27 Readings 12,02.ZIP>> <<NS-29 Readings 12-02.ZIP>> <<NS-31 > Readings 12-02.xls>> <<12-02 Pressure Plots.doc>> > > 1 of 2 1/6/2003 11:03 AM Northstar, 'Plots 12-02 {', l,~ Name: NS -27 Readings 12-02.ZIP NS-27 Readings 12-02.ZIP Type: Zip Compressed Data application/x- zip- compressed) Encoding: base64 Name: NS-29 Readings 12-02. ZIP NS-29 Readings 12-02.ZIP Type: zip Compressed Data appl i cat ion/x- zip - compre s sed ) Encoding: base64 > > Name: NS-31 Readings 12-02.xls > NS-31 Readings 12-02.xls Type: Microsoft Excel Worksheet appl icat ion/vnd, ms - excel ) > Encoding: base64 > > 12-02 Pressure Plots.docName: 12-02 Pressure Plots.doc > Type: WINWORD File (application/msword) ~Northstar Plots, 12-02.doc Name: Northstar Plots, 12-02.doc Type: WINWORD File (application/msword) Encoding: base64 2 of 2 1/&'2003 11:03 AM NS31 Re~dings, 12-02 ,{ l' · Subject: NS31 Readings, 12-02 Date: Mon, 6 Jan 2003 12:45:59 -0600 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer~BP.com> To: Jim Regg <jim_regg~admin.state.ak.us> CC: "- Winton Aubert (E-mail) ' 'AOGCC (E-mail)" <Winton_Aubert~admin.state.ak.us>, "AOGCC Tom Maunder (E-mail)" <Tom_Maunder~admin.state.ak.us> Hi Jim. Give this a try, it's not compressed. Joe ..... Original Message ..... From: Jim Regg [mailto:jim regg@admin.state.ak.us] Sent: Monday, January 06, 2003 9:31 AM To: NSU, ADW Well Integrity Engineer Cc: Tom Maunder Subject: Re: Northstar December Injector Readings pressure plots and NS31 reading are not readable; would appreciate it if you resend just those files. Thanks. Jim Regg "NSU, ADW Well Integrity Engineer" wrote: > Hello Tom. > Attached are pressure/production plots and pressure readings forNS27, NS29 > & NS 31 for December 2002. Notes on the wells: > > NS27's IA was bled down twice during December. The first time was to > maintain the pressure below 3000 psi. The second time was to facilitate a > rig move to the NS24 well. > > NS29's IA was bled down once in December to maintain the pressure below 3000 >'psi. > > There were no NS31 IA bleeds.during December. > I had to compress the attachments to meet the 1 meg email limit. Please > contact Mike Francis or me if you have any questions or problems with the > files. > > Thanks! > Joe > joe Anders, PE / John Cubbon > Well Integrity Engineer > BP Exploration, (Alaska) Inc. > (907) 659-5102 > email: NSUADWWellIntegrityEngineer@bp.com > > <<NS-2? Readings 12,02.ZIP>> <<NS-29 Readings 12-02.ZIP>> <<NS-31 > Readings 12-02.xls>> <<12-02 Pressure Plots.doc>> > > I of 2 1/6/2003 11:04 AM NS31 Readings, 12-02 {' ,ir, · - > Name: NS-2 7 Readings 12-02. ZIP > NS-27 Readings 12-02.ZIP Type: Zip Compressed Data ( appl i cat ion/x- zip - compre s sed ) > Encoding: base64 > > Name: NS-29 Readings 12-02. ZIP > NS-29 Readings 12-02. ZIP Type: Zip Compressed Data (application/x- zip- compressed) > Encoding: base64 > > Name: NS-31 Readings 12-02.xls > NS-31 Readings 12-02.xls Type: Microsoft Excel Worksheet ( appl icat ion/vnd, ms - excel ) > Encoding: base64 > > 12-02 Pressure Plots.docName: 12-02 Pressure Plots.doc > Type: WINWORD File (application/msword) ~NS-31 Readings 12-02.xls Name: NS-31 Readings 12-02.xls Type: Microso~ Excel Worksheet (application/vnd.ms-excel) Encoding: base64 2 of 2 1/6/2003 11:04 AM 6OOO NS31 Injection Pressure IA Pressure · Bleed Flag Injection Rate, MMSCFPD ~lnjection Temperature 3OO 55OO 5OO0 450O 4000 35OO 3000 2500 2OOO 1500 1000 5OO 0 o o 0 o o o o o 275 25O 225 200 = I,=, 175 E 150 : 125 n, 0 100 * 75 50 25 ~KA OIL AND GAS CONSERYA~i~ION COPl~IISSION TONY KNOWLES, GOVERNOR 3.33 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-14.33 FAX (907) 276-7542 November 15, 2002 Mr. Michael J. Francis BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Dear Mr. Francis: The Alaska Oil and Gas Conservation Commission (AOGCC) approved by letter dated February 19, 2002, a request from BP Exploration (Alaska) Inc. (BPXA) authorizing the continued injection of gas into Northstar Wells NS 29 and NS 31. The inner annuli ("IA" - defined as the space between the 9-5/8" casing and 7" injection tubing) of these wells have exhibited pressure increases that appear to be the result of some loss of integrity of the 7" tubing. The AOGCC approvals were granted through October 31, 2002, to allow BPXA time to perform diagnostic testing and complete an assessment of tubular connections. The approval also established operating pressure limits for the annulus pressure, monitoring and monthly reporting requirements. A meeting held on August 6, 2002, with BPXA raised the issue of a long-term apprOval for wells NS 29 and NS 31 to allow these gas injectOrs to continue to operate with known integrity concerns. The meeting also provided an opportunity for BPXA to summarize the status of the tubular connection study. The discussion centered on the frequency of pressure bleed-offs required for maintaining well NS 29 within the pressure limits established in.the AOGCC sundry approvals. It was agreed that BPXA would provide the 'AOGCC with sundry applications addressing the continued operation of NS 29 and NS 31. Since the August 6 meeting, BPXA has advised the AOGCC of similar "tubing by IA communication" in Northstar gas injector NS 27. BPXA requested approval of sundry applications for Northstar Wells NS 29 and NS 31 by cover letter dated October 17, 2002. Interim approval was granted to BPXA through November 15, allowing the continued gas injection into NS 29 and NS 31, while the Commission reviewed the sundry applications. A sundry apPlication dated November 4, 2002, requests a variance to operate NS 27 with tubing by IA communication. The AOGCC has completed a comprehensive review of these sundry applications, the monthly monitoring data Provided by BPXA, and the sUndry applications previously approved on February 19, 2002. Limited information from the Mr. Michael J. Francis November 15, 2002 Page 2 of 3 connection study has been provided to date that would prove useful in the Commission's review, and some questions remain regarding BPXA's intent to repair these wells. Approval to continue gas injection in NS 27, 29 and 31, is authorized through April 30, 2003, subject to the following conditions: o Final results of the connection study must be provided to the AOGCC. Previous sundry approvals for the NS 29 and NS 31 wells obligated BPXA to provide, on a monthly basis, "an assessment of the connection performance and progress of the 3TM party investigation". BPXA has indicated a preference for premium connections in future gas injection well completions at Northstar and detailed installation procedures for the tubing based on this study. A written report that includes representative information supporting recommendations and BPXA decisions about the various types of tubing connections evaluated must be provided to the AOGCC by November 29, 2002. , BPXA must provide results of a hazard study that addresses the operation of gas injectors at Northstar, and must account for the specific conditions of Wells NS 27, NS 29 and NS 31. The hazard study must identify and evaluate the potential hazards, and address how such are mitigated in the Northstar wells to prevent a cascading loss of well integrity. Personnel involved; summary of the findings, and any recommendations for further action must be clearly documented. The hazard study must be provided to the AOGCC by December 13, 2002. 3. Absent specific plans and a timeline for repairs in NS 29, the Commission will not consider extending the approval' to operate 'the well beyond April 30, 2003.. 4. BPXA must provide a complete evaluation of the performance of the premium connection in NS 17 within 30 days of initiating injection. Se Monitoring and reporting must meet the following: a. Continuous monitoring of all wellhead pressures (tubing, IA, OA), temperature and injection rates; b. IA pressure must not exceed 3000 psi; c. All annulus pressure, bleeds and diagnostics must be recorded and 'include fluid type, duration, beginning and ending pressures; d. Monitoring and diagnostic data must be provided monthly to the AOGCC (due by the 5th of each month); e. BPXA must cease injection and notify the AOGCC 'immediately if OA pressure indicates pressure communication or leakage. Mr. Michael J. Francis November 15, 2002 Page 3 of 3 6. Continued operations of NS27 and NS31 beyond April 30, 2003, will be evaluated based on information provided in response to the above conditions. Please contact Jim Regg (793-1236) should you have'any questions. Sincerely, Cammy Oechsli Taylor0 Chair cc: MMS - Regional Supervisor, Alaska OCS Region bp Michael J. Francis, P.E. Senior Petroleum Engineer Northstar BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 661-5111 October 17, 2002 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Phone: (907) 564-4240 Fax: (907) 564-5200 Email Michael. Francis@bp.com Web: www.bp.com RE: NS29 and NS31 Sundry Approval Requests Dear Tom' BP Exploration (Alaska) Inc. seeks sundry approval to allow for the continued operation of the NS29 and NS31 gas injection wells. Both of these wells have tubing by IA communication. For NS29, approval to continue operations until a remediation plan is finalized is recommended. For NS31, approval to operate long term is recommended. In addition to the enclosed Application for Sundry Approval forms and Description Summary of Proposal documents, a slide pack of background information is attached. Please call if you any questions or would like a meeting to discuss these requests. Sincerely, Miclllael J. ~'r~s' Senior Pet~)feum Engineer CC: John Garing Joe Anders/Kevin Yeager John Smart/Gary McBride Krissell Crandall File RECEIVED OCT 1 7 2002 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance X Perforate _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at sudace 1348' FSL, 649' FEL, Sec. 11, T13N, R13E, UM At top of productive interval 1995' FSL, 5090' FEL, SEC 12, T13N, R13E, UM At effective depth 2026' FSL, 219' FWL, Sec. 12, T13N, R13E, UM At total depth 2034' FSL, 5046' FEL, Sec 12 T13N, R13E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service__X (asp's 659822, 6031120) (asp's 660646, 6031785) (asp's 660675, 6031817) (asp's 660684, 6031825) 6. Datum elevation (DF or KB feet) RKB 56.0 feet 7. Unit or Property name Northstar Unit 8. Well number NS31 9. Permit number / approval number 201-060-0 10. APl number 50-029-23009 11. Field / Pool Northstar Unit 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 199' Surface 3192' Intermediate 10882' Liner 658' 11440 feet Plugs (measured) 11280 feet 11356 feet Junk (measured) 11197 feet Size Cemented Measured Depth True vertical Depth 20" Driven 244' 244' 13-3/8" 1534 sx PFE, 470 sx 'G' 3237' 3234' 530 sx Econolite 'G', 977 9-5/8" 10927' 10774' sx Class 'G' 7" 190 sx Class 'G' 10781'- 11439' 10631' - 11280' Perforation depth: measured Open Parrs 11150' - 11170', 11184' - 11304' true vertical Open Perfs 10994' - 11014', 11027' - 11146' Tubing (size, grade, and measured depth 7", 29#, 13Cr TBG @ 10730' MD. Tubing Tail @ 10785' Packers & SSSV (type & measured depth) RECEIVED OCT 17 2002 9-5/8" x 7" BAKER SABL-3 Packer @ 10730'. AJaska 0il & Gas C'0ns. C0mmissio~ 7" HRQ SSSV @ 2037' MD. Anchorage 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch _ 15. Status of well classification as: 14. Estimated date for commencing operation November 1,2002 16. If proposal was verbally approved Name of approver Date approved Oil _ Gas _ Service GAS INJECTION Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Joe Anders / Kevin Yeager, (907) 659 - 5102. Signed '~c~C &,,~ J? ~_, Title: Senior Petroleum Engineer Date January 11, 2001 Michael J. Francis, P.E. Prepared by DeWayne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. . · Bo P TR.~t Plug integrity _ O .. Location clearance __ Mechanical Integrity Te~< Approved by order of the Commission ' '" "~'~ ~ SUBMIT IN TRIPLICATE Form 10-403Rev06/15/88 r~'~q~BFL ML.~ ;~:",, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ 4/ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ ADD PERFS Change approved program _ Pull tubing _ Variance _ Perforate _X Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 56.0 feet 3. Address Exploratory_ 7. Unit or Property name P.-O. Box 196612 Stratigraphic _ Anchorage, AK 99519-6612 Service__X Northstar Unit 4. Location of well at surface 8. Well number 1348' FSL, 649' FEL, Sec. 11, T13N, R13E, UM (asp's 659822, 6031120) NS31 At top of productive interval 9. Permit number / approval number 1995' FSL, 5090' FEL, SEC 12, T13N, R13E, UM (asp's 660646, 6031785) 201-060 At effective depth 10. APl number 2026' FSL, 219' FWL, Sec. 12, T13N, R13E, UM (asp's 660675, 6031817) 50-029-23009 At total depth 11. Field / Pool 2034' FSL, 5046' FEL, Sec 12 T13N, R13E, UM (asp's 660684, 6031825) Northstar Unit 12. Present well condition summary Total depth: measured 11440 feet Plugs (measured) true vertical 11280 feet Effective depth: measured 11356 feet Junk (measured) true vertical 11197 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 199' 20" Driven 244' 244' Surface 3192' 13-3/8" 1534 sx PFE, 470 sx 'G' 3237' 3234' 530 sx Econolite 'G', 977 Intermediate 10882' 9-5/8" 10927' 10774' sx Class 'G' Liner 658' 7" 190 sx Class 'G' 10781' - 11439' 10631' - 11280' ~\09° ti% Perforation depth: measured Open Perfs 11150 - 11170', 11184' - 11304' RECEIVFD true vertical Open Perfs 10922' - 11012', 11026' - 11144" JUN 0 4 2002 Tubing (size, grade, and measured depth 7", 29#, 13Cr TBG @ 10730' MD. Tubing Tail @ 10785' Alaska Oil & Gas c;ons. Packers & SSSV (type & measured depth) 9-5/8" x 7" BAKER SABL-3 Packer @ 10730'. Anchorage 7" HRQ SSSV @ 2037' MD. 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: 06/17/2001 v' 16. If proposal was verbally approved Oil _ Gas __ Suspended _ / Name of approver Date approved Service GAS INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Michael Francis @ 564-4240. Signed !~'~ ~ , )~. ~/", Title: Senior Petroleum Engineer, BPXA, ACT, Northstar Date June 03, 2002 MichaeTJ~.Francis, P.E. f~'jL__.._~ '/ Prepared by DeWayne R. Schnorr 564-5174 -- I / FOR COMMISSION USE ONLY Conditions of approval: Nofify Commission so representative may witness I Approval no. / Plug integrity_ BOP Test_ Location clearance_ t/ ~/I 0 Mechanical Integrity Test __ Subsequent form required 10- Original Signed By Approved by order of the Commission Cammy Oechsli Taylor' Commissioner Date ( ('?! [~),I0 "~ Form 10-403 Rev 06/15/88 · ORIGINAL SUBMIT IN TRIPLICATE BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 03, 2002 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom' Re' Sundry Notice for NS31 to Add Perfs (Ivishak) BP Exploration Alaska, Inc. proposes to add perforations because Northstar is no longer able to reinject all of the produced gas and the required import make- volume. This is a result of increasing GOR~'tha, t have increased the up gas produced gas volume and higher ambient temperature"'that have reduced injectivity. The procedure includes the following major steps: · Pull SSSV, Drift/tag w/dummy gun · Perforate Ivishak from 11090'- 11150' MD, (10935'- 10994' TVD) & from 11304' - 11324' MD (11146' - 11166' TVD). Perforate using Schlumberger 3.375" HSD 3406 P J, 6SPF 60 degree phasing guns. Reference Log SWS GR/AIT Log May 22, 2001. Tie in Log USIT · Run SSSV Sincerely, Micl~ael J. ~n"'ci~, 15~E. Senior Pet~eum Engineer BPXA, ACT, Northstar Background Data: Well: NS-31 APl: 50-029-23009-00 Tree: ABB-VGI 7" 6.5 ksi Tubing: 7" 13-Cr to 10785' MD Tubing Tail: NA- monobore SSSV Nipple: HRQ SVLN @ 2037' MD, 5.963" ID w/7" FXE SSSV (SER # 588927 - 1. NOTE: NO SECONDARY LOCKING DEVICE SENT W/SSSV) GLM: None Packer: Baker SABL-3 @ 10730' MD, 6.00" ID Min ID: 7" RN Nipple @ 10767' MD, 5.77" ID Surf Casing: 13-3/8" L-80 @ 3237' MD (68#/ft.) Intermed. Csg: 9-5/8" L-80 @ 10927' MD (53.5#/ft.) Prod Liner: 7" 13-Cr 10781-11439' MD, liner top ZXP packer, Flex Lock liner hanger PBTD: 11356' MD Max Deviation: 25 deg @ 8669' MD Max Dog Leg: 2.6 deg/100' @ 8385' MD Perforations: 11,150 - 11,170 and11184-11304' MD (140 ft); Perforated with Schlumberger 4.5" 4505 Power Jet, HMX; Penetration: 54", Hole: 0.42", SPF: 5, Phase: 72 deg Reservoir Est. 5175 psi @ 11,100' TVD SS. EMW = 9.0 ppg /' Pressure: WH Pressure: The FTP is +/- 2300 psi. When Shut-in, the SITP is 2600 psi. The possible maximum pressure if well switched out to all NS formation gas is 3760 psi. H2S ppm: none expected ~ Current Status: Gas Injection well. Material Diesel for lubricator testing Required: Waste Waste fluids to be manifested and pumped into disposal well NS-10 or into Disposal: the production manifold. ,/ Last Test: Injecting 120 MMSCFPD at 5202 WHP, 06-03-02 Last TD tag: 11,356' MD 05-29-2001 Last Downhole Perforate/Reset SSSV 11/19/01 Opearation: Contacts: Mike Francis, Engineer 564-4240, cell 529-8678 Wells Group: Cismoski/Romberg 659-5584, pager 659-4236, pgr 124 Note: Northstar is a very sensitive area. All precautions should be taken to prevent spills of any kind durin~l wellwork. TREE: ABB-VGI 7" WELLHEAD:ABB-VGI 13-5/8" 6.5 ksi Multibowl NS31 ORIGINAL RT. ELEV = 55.77' RT/GL. ELEV =40.2' CB/MSL. ELEV: 15.67' SSSV @2037' MD 2034' TVD 7" HRQ SVLN 5.963" ID 13 3/8", 68#/ft, L-80, BTC @3237' __~6.SPPG DIESEL FREEZE PROTECTION AT +/- 2700 7", 29#/ft, 13Cr, NSCC TUBING ID: 6.184" CAPACITY: 0.037 BBI_/FT 7" R NIPPLE, @10709' 5.963" ID (OTIS) 7" R NIPPLE, @ 10755' 5.963" ID (OTIS) 7" RN NIPPLE, @10767' 5.77" ID (OTIS) 7" WLEG, @10785' 6.184" ID (OTIS) 9 5/8", 53.5#/ft L-80, BTC-M @ 10927' Baker SABL-3 PACKER 6.00" ID @10730' MD 10579' TVD 7" LINERTOP @10781' MD 10629' TVD 6.184" ID AN3LEAT'rCPFEFE. N~ PetEr to Ftcduu'ti~ EBfcr t'isto'ic~i ~ d~a Initial Fbff - O'a-oj~: 4505 R:~verJa, ~ F~-,~-a~oz 54"; I-Ue: .42'; Pn~ 72 c~, PBTD @ 11356' MD 11195' TVD TD @ 11439' 7", 29#, 13Cr DATE 6/4/01 7/24/01 REV. BY AGK EMF 11/20/01 COMMENTS Initial Diaqram Add Perf 9/10/01 EMF Inserted TVD Depths EMF Add Perf Northster WELL.- NS31 APl NO:50-029-23009-00 BP Exploration (Alaska) 6000 '- ec[iorl Pressure A Pressure NS31 ,8, :~leed Flag nlection Rate MMSCFPD njuction Tempera'lure 30O 5OOO 4OOO 2 sooo 2000 IOO0 250 5O ii 0 8 8 8 8 8 Lo LO LO CE) Well # NS-31 Balance line between (300 & 500psi) Data Inner Annulus MAX IA 2500# Outer Annulus MAX OA 1000# IA IA Type Amount OA OA Type Amount Date Inject Rate Inject before After Fluid Bleed before After Fluid Bleed Balance IA OA MM/DD/Y Time WHP MMSCFD Temp bleed bleed Bled Bbls bleed bleed Bled Bbls Line Trans. Trans. Intials 5/1/2002 3:30am 3980 0 42 1750 shut in for puls test 0 JG 5/1/2002 7:30am 3996 0 37 1700 shut in for puls test 0 CD 5/2/2002 1:00am 3940 0 43 1570 shut in for puls test 0 JG 5/2/2002 7:55am 4502 0 48 1600 shut in for puls test 0 300 1566 -11 BH 5/2/2002 7:25pm 3917 0 64 1600 shut in for puls test 0 4000 1550 -11 bled Bal. From 4000-250 5~3/2002 7:55am 1726 0 58 1590 shut in for puls test 0 4000 1539 -12 bled Bal. From 4300-100 5/3/2002 1:00pm Puls test finished HP. Down well shut in BH 5~3/2002 7:25pm 3916 0 38 1580 0 100 1537 -11 TK 5/4/2002 4:50am 4235 37 172 2220 18 400 2178 12 HP.online (~ 10:00pm TK 5/4/2002 7:55am 4243 36 171 2250 30 720 2218 29 BH 5/4/2002 7:26pm 4453 55 188 2400 260 200 2360 262 TK 5/512002 12:07pm 4385 0 193 2426 439 HP. Down BH 5/5/2002 6:43pm 4415 48 191 2460 420 250 2417 420 TK 5/6/2002 4:42am 4486 57 195 2525 560 220 2478 555 TK 5/6/2002 8:12am 4502 55 192 2520 560 250 2470 550 BH 5/6/2002 6:59pm 4436 55 195 2400 80 200 2353 72 TK 5/7/2002 8:45am 4422 49 188 2470 385 220 2412 376 BH 5/7/2002 7:19pm 4354 42 190 2505 440 250 2429 424 TK 5/8/2002 8:40am 4146 22 185 2360 180 250 2317 172 BH 5/8/2002 7:40pm 4152 22 186 2375 190 250 2322 193 TK 5/9/2002 7:00am 2390 210 Well shut in (~ 7:30am 250 2333 211 total plant shut down BH 5/9/2002 7:46pm 4029 8 187 2250 0 75 2197 -2 TK 5/10/2002 5:05am 3980 0 187 2200 0 75 2155 0 TK 5/10/2002 8:33am 3976 0 187 2200 0 75 2156 0 BH 5/10/2002 7:36pm 4083 17 187 2360 30 100 2315 58 TK 5/11/2002 4:49am 4082 17 186 2400 90 75 2343 89 TK 5/11/2002 9:15am 4078 17 185 2400 118 75 2350 102 BH 5/11/2002 6:55pm 4096 18 187 2450 175 100 2383 166 TK 5/12/2002 5:04pm 4098 20 184 2450 180 90 2388 176 TK 5/12/2002 7:35am 4101 18 184 2450 185 90 2388 180 BH 5/12/2002 7:44pm 4417 54 192 2650 540 90 2594 534 TK 5/13/2002 10:45am 4704 77 196 2825 745 100 2764 740 BH 5/1312002 3:30@m 5399 134 215 3000 850 gas I 90min. 960- 81 gas 20min. 100 2996 953 BH 5/14/2002 4:48am 4284 41 187 845 0 350 811 -75 TK 5/14/2002 8:50am 4203 28 188 860 0 350 833 -6 BH 5/14/2002 6:43pm 5118 112 207 1000 10 350 961 4 TK 5/16/2002 1:00am 5179 117 193 1000 10 350 989 1 TRW 5/16/2002 4:00am 5194 119 193 1020 400 996 1 TRW 5/16/2002 10:35am 5190 113 204 1100 20 400 1069 17 BH 5/16/2002 7:00pm 5303 120 216 1150 120 400 1127 122 TRW 5/17/2002 5:00am 4973 95 201 1150 20 390 1096 3 TRW 5/17/2002 12:0513m 5159 111 214 1190 20 400 1152 17 TRW 5/18/2002 6:45pm 5522 135 222 1320 540 400 1262 562 TRW 5/18/2002 5:30am 5028 98 198 1200 10 400 1147 I TRW 5/18/2002 8:55am 5040 102 201 1200 10 400 1157 I TRW 5/18/2002 6:45pm 4644 64 194 1200 10 350 1164 1 TRW 5/19/2002 5:00am 4192 23 189 1175 10 350 1128 5 TRW 5/19/2002 8:15am 4192 23 189 1175 10 350 BH 5/19/2002 6:30pm 4178 24 186 1175 10 350 TRW 5/20/2002 5:00am 4177 24 187 1200 10 350 TRW 5/20/2002 8:25am 4164 23 187 1200 10 350 1175 -3 BH 5/20/2002 6:30pm 4192 23 188 1225 10 350 TRW 5/21/2002 5:00am 4161 22 189 1250 10 350 TRW 5/21/2002 7:50am 4161 23 189 1250 10 350 1222 -1 BH 5/21/2002 7:00PM 4844 96 194 1325 10 350 TRW 5/22/2002 4:15AM 5151 114 200 1400 20 390 TRW 5/22/2002 7:55^M 5471 136 215 1500 355 390 1490 368 BH 5/22/2002 12:30PM 5530 136 217 1550 550 400 TRW 5/22/2002 5:30PM 5560 139 220 1600 660 400 TRW 5/22/2002 7:35PM 5580 139 220 1600 665 400 1567 688 BB 5/23/2002 2:45AM 5625 141 219 1620 685 400 1578 712 BB 5/23/2002 7:00AM 4649 146 198 1490 170 400 TRW 5/23/2002 4:30PM 5509 63 217 1600 320 400 TRW 5/23/2002 8:00PM 5550 139 221 1675 655 400 1638 682 BB 5/24/2002 4:15AM 5575 140 218 1670 630 400 1627 645 BB 5/24/2002 7:45AM 5638 143 219 1700 710 400 TRW 5/24/2002 1740 770 400 TRW 5/24/2002 8:00PM 5625 136 229 1795 915 400 1753 937 BB 5/24/2002 8:30PM 960 240 G&D 1Bbl Bled To Tank; 15 Mins. BB 5/25/2002 4:15AM 5600 136 216 1700 15 400 1655 4 BB 5/25/2002 8:30AM 5620 144 217 1725 20 400 1677 12 BB 5/25/2002 7:00PM 5240 110 197 1640 15 400 1585 -1 Problems ~ Caribou Crossin~l BB 5/26/2002 4:00AM 5250 115 199 1645 15 380 1602 -3 Problems (~ Caribou Crossing BB 5/26/2002 7:00am 4694 70 185 1600 10 400 1549 -4 TRW 5/26/2002 4:15pm 1675 10 400 1637 0 TRW 5/26~2002 7:20PM 4720 73 199 1675 15 400 1642 -0.5 WHRU Repairs;Reduced Rates BB 5/27/2002 4:00AM 4825 74 201 1700 15 380 1655 0.6 WHRU Repairs;Reduced Rates BB 5/27/2002 6:30am 4732 74 201 1700 10 400 1659 I WHRU Repairs;Reduced Rates TRW 5/27/2002 5:00pm 4738 75 201 1700 10 400 1679 2 WHRU Repairs;Reduced Rates TRW 5/27/2002 8:00PM 4720 75 201 1725 15 400 1687 4 WHRU Repairs;Reduced Rates BB 5/28/2002 4:15AM 4820 74 200 1730 15 400 1702 4 WHRU Repairs;Reduced Rates BB 5/28/2002 7:20AM 4743 76 200 1740 15 400 1711 5 WHRU Repairs;Reduced Rates TRW 5/28/2002 7:20PM 4825 75 200 1770 15 400 1734 7 WHRU Repairs;Reduced Rates BB 5/29/2002 8:20am 5005 99 198 1800 15 400 1749 2 TRW 5/29/2002 4:10pm 5647 146 217 2000 120 400 1959 123 TRW 5/2912002 7:15pm 5625 147 216 2025 220 400 1978 225 BB 5/30/2002 4:20AM 5250 110 196 1880 15 380 1817 1 Caribou Crossing Down BB calibrate flow transmitter 5/30/2002 7:00am 5371 126 204 1900 15 400 1859 5 FI-0031 most of day TRW 5/30/2002 3:40pm 5408 127 215 1975 60 400 1919 71 TRW 5/30/2002 7:15PM 5525 128 216 2000 125 400 1945 116 TP PI 5465# BB 5/31/2002 4:15AM 5675 132 220 2050 255 400 2000 259 TP PI 5582# BB 5/31/2002 7:00AM 5653 132 217 2025 250 400 1990 250 TRW 5/31/2002 4:00PM 5677 131 226 2150 490 400 2101 507 TRW 5/31/2002 7:45PM 5675 131 227 2150 475 400 2101 493 TP PI 5608# BB Well # NS-31 Balance line 300#< 500# Data Inner Annulus MAX IA 300ff/f Outer Annulus MAX OA 1000# Inject Rate Inject IA Bled IA Type Amount OA Bled OA Type Amount Date MMSCFD Temp before Pressure After Fluid Bleed before Pressure After Fluid Bleed Balance TP OA MM/DD/Y Time WHP bleed YiN bleed Bled Bbls bleed Y/N bleed Bled Bbls Line Trans. IA Trans. Trans. Comments Intials 6/1/2002 3:30AM 5675 132 219 2080 300 400 5647 2036 309 BB 6/1/2002 7:00am 5659 133 216 2075 260 400 2028 264 TRW 6/1/2002 4:00pm 5373 124 217 2050 15 400 2023 8 TRW 6/1/2002 7:25PM 5475 127 209 2080 35 400 5349 2020 23 BB 6/2/2002 3:40AM 5425 127 207 2050 15 400 5339 1988 2 B B 6/3/2002 8:00am 5253 121 206 2125 10 200 2091 4 TRW AI,ASIL~ OIL AND GAS CONSERYA~ION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 February 19, 2002 Fritz Gunkle Northstar Delivery Manager BP Exploration (Alaska) Inc. ? O Box 196612 Anchorage, AK 99519-6612 RE: Request for Injection Variance NS29 PermitNoI 201-041 Sund~ApprovalNo: 302-016 .~.;NS3. I'"::.: ::permit.'.'i~b'::.'"'::20'.i..~060'. ~..SU~ Xppr°val"No:','' 3'02:017 BP Exploration (Alaska) Inc Dear Mr. Gunkle: BP Exploration (Alaska) Inc. ("BPXA") has requested authorization to continue injection in the NS29 and NS31 wells on Northstar Island. Both wells are injectors that have exhibited slow pressure build-ups on the 9-5/8" x 7" annulus (the inner annulus or "IA"). BP has commissioned an independent 3rd party to assist with the diagnostics and investigation of the tubular connection used on the 7" tubing set in each well. The information provided by BP demonstrates through the monitoring information that the pressure build-ups are slow, that all pressures are contained within the wellbore and that the 9-5/8" casing has integrity. The Applications for Sundry Approvals to continue injection in both wells are approved subject to the following specific conditions: . Absent further determination, the approvals expire October 31, 2002. Injection operation is contingent on performance of' a monitoring and reporting plan that includes a. Limiting the IA pressure to a maximum of 3000 psi; b. Continuous monitoring of wellhead pressures, temperature and injection rates; c. Recording all IA bleeds, including fluid type, duration, starting pressure and ending pressure; d. Performing an IA fluid level once per quarter; e. Submitting a monthly report of daily pressures, temperatures, injection rate and IA bleed data; f. Including in the monthly report any other relevant data collected during the month including an assessment of the connection performance and progress of the 3rd party investigation. February 4, 2002 , ~,' Page 2 of 2 "i ~ 3. If it becomes necessary to bleed the IA more than two times per week, notify the AOGCC within 24 hours and secure authorization to continue injection. 4. Contact the AOGCC within 24 hours if the monitoring information and pressure bleed cycles indicate that potential "leak rates" are increasing. If you have any questions, please contact Tom Maunder, AOGCC Senior Petroleum Engineer at 793-1250. Sincerely, Cammy (Yechsli Taylor 0 Chair COT:\jjc Note to File BP Sundry Request for Northstar Injectors N S29--201-041 --302- 016 NS31 --201-060--302- 017 SUMMARY On January 11, 2002, following a meeting with Tom Maunder, BP submitted sundry notices for the respective 'wells. The sundries request approval to continue or resume injection of natural gas (produced and imported) into the wells. The reason for these requests is that inner annulus pressure of each well has not stabilized after allowing operating temperatures to reach equilibrium. The purpose of this document is to document the assessed condition of the wells while operating, review the increased monitoring actions proposed by BP and to recommend that the Commissioners approve BP's proposal. HISTORY In mid November, BP notified Tom Maunder that, NS29, the initial gas injection well on Northstar Island was experiencing unstable inner annulus (IA) pressures. While the well was operating, the IA pressure was observed to steadily increase at the rate of about 350 psi per day. BP requested approval to perform diagnostic tests which included close observation of the well's operating parameters. The Commissioners were appraised of this information. BP's request was approved, however they were advised that preparations should be made to ready another injection well should the diagnostics determine that continued injection into NS29 was not appropriate. BP moved ahead and prepared NS31 which was presently producing for conversion to injection service and initiated injection in early December. The diagnostic tests on NS29 in the interim had been indeterminate. Performing definitive tests on the operating well were difficult and potentially risky. During the diagnostic period, BP had been able to determine that the build up rate remained essentially unchanged, although process plant shutdowns and startups gave some variability to the observed data. The IA could be bled to atmospheric pressure and a small gas meter was employed and a maximum gas flow of 765 cubic feet per hour was measured. Following the startup of NS31, NS29 was killed, a tailpipe plug set. With fluid in both the tubing and IA, the well successfully passed a series of MITs. When completed, the well had passed similar MITs. When NS31 was brought online and operating temperatures allowed to stabilize, plans were made to perform the normal MIT. The long practice of the AOGCC is the standard pressure testing performed when a well is constructed provide "provisional" approval for the well to begin injection service. The Inspectors normally witness a MIT after the well has been put in service and operating temperatures stabilized. At that time, BP expressed some reservation regarding the standard testing procedure. Their concern was that the tubing connection could be potentially damaged by the application of external pressure. A series of discussions were held and the concerns resolved and NS31 successfully passed a standard MIT test on December 8. This test was witnessed by Lou Grimaldi. After allowing the wellbore temperatures to stabilize (about 2 weeks), NS31 exhibited the same IA pressure trend seen on NS29. After providing notice, BP has been continuously observing the IA pressure and bleeding the pressure down when it approaches 2500 psi. The build up rate appears to be about 250 psi per day. ASSESSMENT AND ACTION PLAN Unstable operating pressures such as exhibited by these 2 wells are of concern. The expectation is that when the operating temperatures have stabilized, the pressures should as well. Similar IA pressure behavior has not been observed on the 35 gas injection wells in service at Prudhoe Bay. In discussions with BP engineers, it has been noted that the production wells on Northstar have stable IA pressures. The observed pressures are contained within the production casing. There is no evidence of pressure communication outside the 9-5/8" casing. At this time, BP has commissioned a 3rd party investigation of the tubular connection employed on the 7" tubing set in each well. NSCC (Nippon Steel Casing Connection) has been used previously on the North Slope. The connection has 2 metal-to-metal seals and does not employ a seal ring. The commissioned investigation will look at the connection performance under Northstar load conditions. They are also examining the records regarding how the specific tubulars were shipped, handled and eventually run. In the interim BP has proposed that NS31 be allowed to remain in service and NS29 be returned to service with a strict observation protocol in place on both wells. BP has a "complete" computer controlled monitoring system in place to observe and record the injection rates, pressures and temperatures on these wells. Both the IA and OA are also monitored. The various data points are scanned at intervals of 5 seconds or less. Individual alarm values can be set to alert the operating crew of a problem. Their operation center on the island is manned continuously. In addition to the automatic monitoring, BP also proposes to obtain manual pressure reading hourly. They request to be allowed to operate each well with a maximum allowed pressure of 3000 psi on the IA. It is their stated intent to keep the IA pressures within an envelope between 1000 and 2500 psi. When an IA pressure approaches 2500 psi, it will be bled down via an adjacent flowline to 1000 psi. Depressuring events will also be logged. The gathered information will be forwarded to the Commission monthly. Fluid level determinations and MITs are also proposed. The 3000 psi proposed maximum IA pressure is well below the rated burst pressure of the 9-5/8" casing. The published burst pressure for 9-5/8", 53.5#, L- 80 pipe is 7930 psi. When the wells were originally completed, the fluid packed lAs were successfully tested to 5500 psi. This test is in excess of the maximum surface injection pressure. The manner in which BP has prepared the sundries implies that provided the wells remain in the presently described condition that gas injection could be allowed indefinitely. Senior Staff does not agree with this interpretation and feels that a more limited time period is appropriate for this situation. RECOMMENDATION Based on the information provided by BP and a review of that information by Senior Staff, the following recommendations are made: 1. Approve the subject sundry requests submitted by BP. 2. Absent further determination, the approvals expire October 31, 2002. 3. Injection operation is contingent on performance of the monitoring and reporting plan as outlined in the sundry applications. 4. Authorization to continue injection may be revoked if the monitoring information and pressure bleed cycles indicate that potential "leak paths" are increasing. 5. As BP develops information with regard to this matter, the analysis'should be provided to the Commission. 6. Recommend that the available information regarding the connections and well performance be reviewed by BP and AOGCC not later than early September. 7. Prepare a transmittal letter to BP advising them of the approval, expiration date and other points detailed above. Thomas E. Maunder, PE Sr. Petroleum Engineer r. Reservoir Engineer NS31 Injection Pressure 6OOO 5500 ¢ 12/2/2001 12/12/2001 Injection Rate- Blue- NS31 m~ter, Purple HPA meter Injection Temperature 50OO 4000 3500 3ooo 12/22/2001 1/1/2002 1/11/2002 1/21/2002 1/31/2002 1500 IAI'~N. Pressure 1000 5OO 0 2/I0/2002 ,.~,S-29 & NS-31 Monthly Report, 01-02 Subject: NS-29 & NS-31 Monthly Report, 01-02 · Date: Mon, 4 Feb 2002 00:27:22 -0600 From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@bp.com> To: "AOGCC Tom Maunder (E-mail)" <Tom_Maunder@admin.state.ak.us>, "AOGCC - Winton Aubert (E-mail)" <Winton_Aubert@admin.state.ak.us> Hello Tom and Winton. Attached are injection plots for NA-29 & NS-31. The Excel files that contain the pressure data are too large to email, these are Word files with a picture of each plot. Notes on the wells: NS-29: Currently SI with a TTP. Date range presented is when the well was on injection. Scheduled to have SL pull the TTP between 2/5-10/02. <<NS-29 02-01-02.ZIP>> <<NS-31 02-01-02.ZIP>> We will refine the plot format and present a more consistent presentation next month. Please call if you have any questions, would like additional information or a different plot presentation. Joe Joe Anders, P.E. / Kevin Yeager Well Integrity Engineer BP Exploration, (Alaska) Inc. (907) 659-5102 email: NSU^DWWelllntegrityEngineer@bp.com [~NS-29 02-01-02.ZIP Name: NS-29 02-01-02.ZIP Type: Zip Compressed Data (application/x-zip-compressed) Encoding: base64 ~NS-31 02-01-02.ZIP Name: NS-31 02-01-02.ZIP Type: Zip Compressed Data (application/x-zip-compressed) Encoding: base64 ;;)-%. I of I 2/4/02 8:51 AM 25O Injection Temp ~ NS 29 Injection History Injection Rate MMSCFPD + IA Pressure .Injection Press --.~ -- Bleed Flag 5,000 200 150 100 50 0 11/12/01 11 / 19/01 11/26/01 Press Inj Temp IA Press Inj Rate 12/3/01 4,500 4,000 3,500 3,000 "' < 2,500 P 2,000 "' 0 1,500 _¢ 1,000 5OO NS31 300 275 250 225 2O0 n, 175 P 150 "" 125 E 100 I Injection Pressure J · · AA · · · · · · · · · ,A . , ., J~ . ~, . · -- * ! I Injechon Temperature ~ ~t ', '. ,_ '---.'£'-,,: ~ Ic, . IA.d , ~_,~,.a=~--~ ~_~a_ ,, ', , , ., .,' ..._.- __ :',, ~ ~ I ,nj.,=.on,~,..-B,ue-.~:,', mo,er..ur,.,e,-,.^ =,,,er L ;"" ~b · t ,. , . ... . . - Pressure · ~'. :, -° . · . · ~ · ·,~. · · · ~ '~., ~; t .~:'.,? . : . · * I...~· ~ '* ~. , , 75 50 25 0 12/2/2001 60OO 55OO 12/12/2001 12/22/2001 1/1/2002 1/11/2002 1/21/2002 1/31/2002 5OO0 45OO 4OOO 35OO 3000 2500 2000 1500 IOO0 5OO 0 2/10/20O2 Estimated Completion Date of NSCC Connection Testing Subject: Estimated Completion Date of NSCC Connection Testing Date: Fri, 18 Jan 2002 11:09:28 -0600 From: "Francis, Michael J" <Michael. Francis@BP.corn> To: "'tom_maunder@admin.state.ak.us'" <tom_maunder@admin.state.ak. us> CC: "Schultz, Mikel" <Mikel. Schultz@BP.com>, "Hernandez, Floyd" <HernanFl@BP.com>, "Turnbull, Bill F" <tumbuwf@BP.com> Tom, The third party NSCC connection testing should be finished by sometime in April. We should also be able to finish our review of running procedures in this time frame. Please let me know if you need any additional information before you go to the commissioners. Thanks, Mike Francis BP Exploration Alaska, Inc. Alaska New Developments - Subsurface Team Senior Petroleum Engineer Phone: (907) 564-4240 Cell: (907) 529-8678 Fax: (907) 564-5200 e-mail: Michael. Francis@bp.com I Type: application/ms-tnef' ~-~ Part 1.21 Encoding: base64 1 of I 1/19/02 3:19 PM NorthstCrr Northstar Injection Well Discussion ObP oNS29 Test Results · NS31 Status · Proposed Operating Plan · Projected Injection Needs oNSCC Threads Northst'~'r NS29 Test Results O bp · Tubing HP MIT- Passed x~o~(~,~,~ · IA HP MIT- Passed ~o.,~ l.~xo-,'a ~,~ · Gas Rate Leak Test- Max rate observed 765 scfh · Based on the MIT results, the planned diagnostics (video camera and noise/temperature log) were cancelled (leak too small to detect). Northstar NS29 Test Results MIT with initial IA pressure of 2650 psi and tubing pressure of 0 IA Total Test Time, Pressure,IncrementalPercentage Min psi P Loss, psipressure loss Comment 0 2650 0 15 2635 15 0.57% 30 2635 0 0.57% << 10% 60 2630 5 0.75% MIT with intial tubing pressure of 5000 psi and lapressure Tubing Total Test Time, Pressure,IncrementalPercentage Min psi P Loss, psipressure loss Comment 0 5OOO - 0 15 4980 20 0.40% 30 4960 20 0.80% << 10% 45 4950 10 1.00% 60 4940 10 1.20% 75 4930 10 1.40% 90 4930 0 1.40% 105 4925 5 1.50% O bp Northstar NS31 Status 0 bp · Injecting Gas oqi - 120 mmscfd oPinj - 5104 psi · WHT - 185 F · IA- 2216 psi oOA- 812 3OO ] 2761 250 J 225 2OO ~ 175 150 t25 100 -- 75- 12/2/200I NS31 Pressure - 5500 4500 4ooo ---- 3500 .... j Injection Temperature ~ injection Rate- Blue-NS3t meter, Purple HPAmeter 3000 .......... 2500 2000 1500 ~ IANN ~ Pressure. _ ~ 500 Period with frozen sensor line / 2/9, 2001 12/16/2001 12/23 2001 I2/3C I2001 1/6/2002 1/I 3/2002 Northst'3tlrr NS29 Proposed Plan to Return to Injection O bp Request to return to injection is supported by: MITIA Passed on 12/20/01, positive differential into tubing. MIT-T Passed on 12/21/01 against a TTP. Measured Gas Rate < 900 SCF/Hour. ~.~,\,- ,-,~- *,-- s~c~-k-'-I '~a\"~ Production Casing pressure rated > injection pressure. Proposed Variance Stipulations: Limit lAP to 3000 psi. Install pressure sensors and high pressure alarms. Monthly report of well pressures, rate and temperature. Include bleed logs. No~h~t~r Exam ,~nd Plot bp Exam le IA Alarm Setbn s PV Limit Alarms AL1 P',/Hi91 F~ Setpou-lt ~ Output ~ Mode Alarm Acknowledgement Limit Priority Subpriority 1250 Or' iH rib Subpr onty 0 ©efi___%e/aarrn MessafLea Deadband Northst"~ .~* Exam le OA Alarm Setbn s PV Limit Alarms Ty. pe PV HiHigh Control Fall Alarms j-- PV ~ :~ etpo~nt ~ Output ~; Mode Limit Priority Subpdority 220 O0 ZJ 4n 00 i ~iJ Deadband Alarm Acknowledc~ement AJarm Message Irlde~ i Cl Define Norihst~r ~ Exam te Plantsca e Sna shot Northst'/t~'r Example of Local IA Monitoring O bp ! Data Inner Annulus Injection Injection Differentia Rate Temp IA I From Bled IA Amount Date MMSCF/ ('1-1'- before last Wellhead Press.Y/ After Type Bleed MM/DD/Y ]3me D 0031A) bleed reading pressure N bleed Fluid BledBbls 1/2/2002 1:00 AM 113 175 2340 0 5000 N 1/2/2002 2:00 AM 114 172 2325 -15 5000 N 1/2/2002 3:00 AM 113 172 2305 -20 4970 N 1/2/2002 4:00 AM 110 174 2300 -5 4980 N 1/2/2002 5:00 AM 113 171 2340 40 5000 N 1/2/2002 6:00 AM 112 169 2380 40 4971 N 1/2/2002 7:00 AM 109 174 2390 10 4961 Y 1600 G & D 25 MIN 1/2/2002 8:00 AM 113 174 1595 -795 4973 N 1/2/2002 9:00 AM 112 172 1667 72 4973 N 1/2/2002 10:00 AM 110 175 1770 103 4975 N 1/2/2002 11:00 AM 111 178 1697 -73 4982 N 1/2/2002 12:00 PM 111 176 1689 -8 4981 N 1/2/2002 1:00 PM 112 175 1685 -4 4979 N 1/2/2002 2:00 PM 110 179 1713 28 4982 N 1/2/2002 3:00 PM 110 179 1718 5 4979 N 1/2/2002 4:00 PM 110 179 1725 7 4977 N 1/2/2002 5:00 PM 112 178 1717 -8 4980 N 1/2/2002 7:00 PM 112 188 1720 3 5000 N 1/2/2002 8:00 PM 112 188 1721 1 5000 N 1/2/2002 9:00 PM 112 188 1740 19 5000 N 1/2/2002 10:00 PM 112 188 1740 0 5000 N 1/2/2002 11:00 PM 111 180 1750 10 5000 N 1/2/2002 12:00 AM 111 192 1800 50 5000 N 1/3/2002 1:00 AM 111 192 1825 25 5000 N 250 NS 29 Injection History Temp ----- Injection Rate MMSCFPD ~lA Pressure --Injection Press ~ Bleed Flags bp 6,000 5,000 200 100 4,000 3,000 2,000 5O 1,000 0 0 10/31/01 11/7/0t 11/I4 11/21/01 11/28/01 12/5/01 Northstar NS-CC Connection Data From NIPPON WebpageO bp NS-CC Features · Excellent gas Seal Tightness pressure and combined load. - Unique metal to metal radial seal is reliable at high · Low Hoop Stress - Resultant hoop stress due to make-up and internal pressure is kept ~-~ below SMYS (Specified Minimum Yield Strength) a most desirable feature for sour environment. · Thread Lubricant Pressure Release Feature - Box thread root is deeper to allow excess thread lubricant pressure to be released. · High Joint Strength - Same as APl Buttress. · Anti-Galling - seal and thread Eliminates "over-doping" problems. Excellent anti-galling performance is assured due interference, and proper thread surface coating. to suitable design of · Less Turbulent Flow olnterchangeability- All NS-CC connections within a given size are interchangeable NS-CC Connection Data - From NIPPON Webpage~ CONNECTION ~OR CA~ItNG Northst'A'r NS-CC Connection Data O bp NS-CC - BPXA History, Plans · Historically used on Cr 13 tubulars in HP conditions (BP Class 2 service) · All metal to metal seals are torque turned ' This is the Highest Pressure Gas Service to date at BPXA (PBU injectors +/- 3500 psi) 7-, ~- ~r-~.,s~.~ ~ ~.o~ ?~.~ · BP UTG will conduct testing on this connection (internal and external pressure tests under loading conditions · FEA analysis will also be conducted if needed · BPXA is reviewing running procedures · BP has switched to from Nippon to Sumotomo (VAM-ACE) as their world wide supplier, for commercial reasons. 100.00 90.000 80,000 70,000 60,000 50,000 40,000 2002 Ramp up and well schedule Max instantaneous Well Potential ~NS16 ~e NS07 ~;.'~ NS 15 NS08 NS14 NS09 NS13 ~NS31 NS27 ~ Field actual 20,000 10,000 current drilling schedule and 10 day POP time. TREE: ABB-VGI 7" 6.5 ksi NS31 ORIGINAL RT. ELEV -- 55.77' WELLHEAD:ABB-VG, (" ------ i:] T/GL. ELEV =40.2' 13-5/8" 6.5 ksi Multibowl 1 CB/MSL. ELEV = 15.67' / I HRQ SSSV @2037' MD 2034' TVD I i 7" HRQ SVLN 5.963" ID ~6.8PPG DIESEL FREEZE PROTECTION AT +/- 2700 13 3/8", 68#/ft, ~~ J · I L-80, BTC (~3237' , 7", 29#/ff, 13Cr, NSCC TUBING ID: 6.184" CAPACITY: 0.037 BBL/FT , 7" R NIPPLE, @10709' : 5.963" Id (OTIS) I I 7" r NIPPLE, @ 10755' ~;~ ~;~ ~ Baker SABL-3 PACKER 5.963" ID (OtiS) I I 6.00" ID @10730' MD 10579' TVD 7" RN NIPPLE, @10767' ~ 5.77" ID (OTIS) I 7" WLEG, @10785' 6.184" ID (OTIS) 1~4 7" LINER TOP @10781' MD 10629' TVD 6.184" ID 9 5/8", 53.5#/ft L-80, BTC-M @10927' ~~ · Fa:USa (]~'r(~) F~hL~ AN~LF_ATT~FE~. H~.4~'; R~ ~j [1 5 1118~- 1130~ 11(~-1114~ O~n 7/14/2001 5 1115~-1117~ 1C~2-11012 q~n 11/19'~01 PBTD @11356' MD 11195' TVD DATE REV. BY COMMENTS Northstar 6/4/01 AGK Initial Diagram WELL-. NS31 7/24/01 EMF ,Add Perf APl NO:50-029-23009-00 9/10/01 EMF Inserted TVD Depths 11/20/01 EMF ,Add Per[ BP Exploration (Alaska) 13-5/8" 6.5 ksi Multibowl ~ CB/MSL. ELEV = 15.57' [ HRQ SSSV @2017' MD 1902' TVD 7" HRQ SVLN 5.963" ID ~6.SPPG DIESEL FREEZE 13 3/8", 68#/ft, .~ ~, PROTECTION AT 3000' L-80, BTC @3798' 7", 26#/ft, L-80 NSCC TUBING ID: 6.276" ' CAPACITY: 0.0382 BBL/FT I 7" R NIPPLE, (~13093' 5.963" ID (OTIS) 7" R NIPPLE, (~ 13,139' ;~ i~ ~ Baker SABL-3 PACKER 5.963" ID (OTIS) ~ ! I 6.00" ID (~13114' MD 10599' TVD 7" RN NIPPLE, (~13150' ~ 5.77" ID (OTIS) 7" WLEG, @13169' ~ ~1 i~i~ 7" LINER TOP ~;~13156' MD 6.184" ID (OTIS) 10636' TVD 6.184" ID 9 5/8", 53.5#/ft L-80, BTC~M @13342' ~ '~ · PER~OP, ATtDN SLIVfv~RY REF LOG: USIT/GR/CCL (06/05/01) ANGLE AT TOP PEF~: Note: Refer to R'oduction DB for historical pen' data · 13576' - 13656' 11011'-11084' Opn 6/23/2001 PBTD @13667' MD 11094' TYD - - TD @13679' 7", 29#, L-80 NSCC DATE REV. BY COMMENTS Northstar 2/12/01 SWC Initial Diagram WELL.- NS29 5/23/01 SWC Updated Casing Depths APl NO: 50-029-23005-00 6/11/01 SWC Updated Comp Equip Depths 7/10/01 EMF Add Perf BP Exploration (Alaska) 9/10/01 EIV}~ Inserted TVD Depths BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-24 Anchorage, Alaska 99519-6612 bp January 11,2002 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: NS-29 (PTD 2010410) Application for Sundry Approval NS-31 (PTD 2010600) Application for Sundry Approval Dear Mr. Maunder: Attached is Application for Sundry Approval form 10-403 for wells NS-29 and NS-31. These requests are for approval to continue gas injection in wells exhibiting slow IA re- pressurization. A description summary of proposal and wellbore schematic is included for each well. If you require any additional information or clarification, please contact either Kevin Yeager or me at (907) 659-5102. You can also contact Mike Francis at 564-4240. Sincerely, Joe Anders, P.E. Well Integrity Engineer Attachments RECEIVED JAN 1 .~. 200Z Alaska 0il ii, Gas C0~s, Commissi0r~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance X Perforate _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1348' FSL, 649' FEL, Sec. 11, T13N, R13E, UM At top of productive interval 1995' FSL, 5090' FEL, SEC 12, T13N, R13E, UM At effective depth 2026' FSL, 219' FWL, Sec. 12, T13N, R13E, UM At total depth 2034' FSL, 5046' FEL, Sec 12 T13N, R13E, UM 5. Type of Well: Development _ Exploratory __ Stratigraphic _ Service__X (asp's 659822, 6031120) (asp's 660646, 6031785) (asp's 660675, 6031817) (asp's 660684, 6031825) 6. Datum elevation (DF or KB feet) RKB 56.0 feet 7. Unit or Property name Northstar Unit 8. Well number NS-31 9. Permit numb.e[ / approvaL.number -' :' 'l-.:;" i:~".,-" ',;" ' ~ ..?, !-/,.~:...,~,_.l-.~OBO:-O · 10, APl number 50-029-23009 11. Field / Pool Northstar Unit 12. Present well condition summary Total depth: measu red true vertical Effective depth: measured true vertical Casing Length Conductor 199' Size 20" 11440 feet Plugs (measured) 11280 feet 11356 feet Junk (measured) 11197 feet Cemented Driven Measured Depth 244' True vertical Depth 244' Surface 3192' Intermediate 10882' Liner 658' 13-3/8" 1534 sx PFE, 470 sx 'G' 530 sx Econolite 'G', 977 9-5/8" sx Class 'G' 7" 190 sx Class 'G' 3237' 10927' 10781'-11439' 3234' 10774' 10631' - 11280' Perforation depth: measured Open Perfs 11150'- 11170', 11184'- 11304' true vertical Open Perfs 10994' - 11014', 11027' - 11146' Tubing (size, grade, and measured depth RECEIVED J/ N .1 1 2002 Alaska 0il & Gas Co~s. Commission Anchorage 7", 29#, 13CrTBG @ 10730' MD. Tubing Tail @ 10785' Packers & SSSV (type & measured depth) 9-5/8" x 7" BAKER SABL-3 Packer @ 10730'. 7" HRQ SSSV @ 2037' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation 1 January 10, 2002 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Suspended Service GAS INJECTION 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Joe Anders / Kevin Yeager, (907) 659 - 5102. Signed' /~/d~ ~'v~~ Title: Well lntegrity Engineer Date January11,2001 Joe Anders~ P.E. Prepared by DeWayne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ApprovM no. . _ Plug integrity __ BOP Test_ Location o,e~,~,o~ _ I .~ -0[ Mechanical Integrity Test__ Subsequent form required 10- q Oq .t~O1~,~..~%..~.%~?~ ~.~_~,~> t't¢,,.~11~4~ inal Signed By Approved by order of the Commission r, .... r~.._,, m,,. , , , A ~ Commissioner Date I N A L Form 10-403 Rev 06/15/88 · . SUBMIT IN TRIPLICATE NS-31 Description Summary of Proposal 01/11/02 Problem: Gas Injector with slow IA re-pressurization Well History and Status Well NS-31 (PTD 2010600) is an injector that exhibits IA re-pressurization. Bleeds are occurring 1-2 times per week to keep the IA pressure under 3000 psi. The IA pressure is observed to increase appr, pximately 300 psi/day, depending on injection temperature and pressure. On 12/08/01, an MITIA passed to 2700 psi with the well on injection. Summary of recent events: > 12/08/01: MIT IA passed (2700 psi) while well on injection. This sundry request is to allow for continued injection of gas. The following supports the request: A MITIA Passed on 12/08/01 to 2700 psi, demonstrating competent production casing. /,- Pressures, te,,m'perature and injection rate will be monitored and recorded daily. An annual IA leak rate test will be.,,c, dnducted to monitor the leak severity. An MITIA will be conducted every 4 years to confirm casing i.i~egrity. The Production Casing pressure rating > injection pressure. Proposed Action Plan 1. Allow well to continue gas injection. 2. Limit the maximum IA pressure to 3000 psi. . 3. Record wellhead pressures, temperature and injection rates daily. Also record IA bleeds. 4. Submit a monthly report of daily pressures, temperatures and injection rate. 5. Perform an IA fluid level once a quarter. 6. Perform an IA leak rate test once a year. 7. Perform an MITIA once every//r years. ~ 8. Notify the AOGCC if the leak rate increases to a high enough rate to log. IIII TREE: ADB-VOl 7" 6.5 ksi ( NS31 i" IGINAL RT. ELEV = 55.77' WELLHEAD:ABB-VGI "..,/GL. ELEV =40.2' ,13-5/8" 6.5 ksi Multibowl ...... " CB/MSL. ELEV = 15.67' [-- -- ~HRQ SSSV @2037' MD 2034' TVD 7" HRQ SVLN 5.963" ID ~6.8PPG DIESEL FREEZE PROTECTION AT +/- 2700 13 3/8", 68#/ft, ~,~ ~, L-80, BTC @3237' i I , , 7", 29#/ft, 13Cr I TUBING ID: 6.184" CAPACITY: 0.037 BBL/FT 7" R NIPPLE, @10709' 5.963" ID (OTIS) -- --I I 7" R NIPPLE, (~ 10755' E~ [] __ Baker SABL-3 PACKER 5.963" ID (OTIS) ~I I6.00" ID @10730' MD 10579' TVD 7" RN NIPPLE, (i~10767' ~ --I I 5.77" ID (OTIS)" 7"WLEG,@10785'~ ~1 I~;~ 7" LINER TOP @10781' MD 6.184" ID (OTIS) 10629' TVD 6.184" ID 9 5/8", 53.5#/ft L-80, BTC-M @10927' ~'~ i,. PERFORATION SUMMARY REF LOG: GR/AF (5/22./01) [Tie-In Log: GR/CCL/USrI'] ANGLE AT TOP PEP, F: Note: Refer to R'oduction DB for historical perf data Initial Perf- Charge: 4505 Pow er Jet, HMX; Penetration: 54"; H01e: ,42"; Phase: 72 deg ["~ 5 11184'- 11304' 11026'-11144' 0pn 7/14/2001 4'5 5 11150'-11170' 10992'-11012' 0pn 11/19/2001 PBTD @11356' MD 11195' TVD TD @11439' '~ ~' 7", 29#, 130r DATE REV. BY COMMENTS Northstar 6/4/01 AGK Initial Dia,qram WELL: NS31 7/24/01 EMF Add Perf APl NO:50-029-23009-00 9/10/01 EMF Inserted TVD Depths 11/20/01 EMF Add Perf BP -~, .,:x~"ora*iont ..)/Alas"a~''' S4~5E SPF F,rl'ERVAL MD I INTERVAL'~/D Opn/Sqz DATE 5 11184'-11304'I 11026'-11144' Opn 7/14/2001 · 4'5 5 11150'-11170' 10992'-11012' Opn 11/19/2001 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Converted Producer to MI Inject P~ tubing_ Stimulate _ Plugging _ Alter casing _ Repair well _ Perforate _ Other_X Convert to MI Inject 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1348' FSL, 649' FEL, Sec. 11, T13N, R13E, UM At top of productive interval 1995' FSL, 5090' FEL, Sec. 12, T13N, R13E, UM At effective depth 2026' FSL, 219' FWL, Sec. 12, T13N, R13E, UM At total depth 2034' FSL, 5046' FEL, Sec. 12, T13N, R13E, UM 5. Type of Well: Development __ Exploratory__ Stratigraphic__ Service__X (asp's 659822, 6031120) (asp's 660646, 6031785) (asp's 660675, 6031817) (asp's 660684, 6031825) 6. Datum elevation (DF or KB feet) RKB 56 feet 7. Unit or Property name Northstar Unit 8. Well number NS31 9. Permitnumber/appmvalnumber 201-060 10. APInumber 50-029-23009 11. Field / Pool Northstar Unit 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 119' 3192' 10882' 658' Intermediate Liner 11440 feet Plugs (measured) 11280 feet 11356 feet Junk (measured) 11197 feet Size Cemented 20" Driven 13-3/8" 1534 sx PFE, 470 sx 'G' 530 sx +Econolite 'G', 977 9-5/8" sx Class 'G' 7" 190 sx Class 'G' Measured Depth 244' 3237' 10927' 10781'-11439' True Ve~ical Depth 244' 3234' 10774' 10631'-11280' Perforation depth: measured Open Perfs 11150' - 11170', 11184' - 11304' true vertical Open Perfs 10992' - 11012', 11026' - 11144' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 7", 29#, 13 CR TBG @ 10730' MD. Tubing Tail @ 10785'. 9-5/8" x 7" BAKER SABL-3 Packer @ 10730'. 7" HRQ SSSV @ 2037' MD. RECEIVED DEC I 2001 Alaska 0il & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 11/27/01 Subsequent to operation 12/07/01 OiI-Bbl 17500 Representative Daily Average Production orlniection Data Ga~Mcf Wate>Bbl 38500 0 MIl~ection 70000 0 Casing Pre&sum Tubing Pressure 1900 438O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ ~. Gas__ Suspended__ Service MI Gas Iniection Well 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ncl~'~ ' Title: Sr Petroleum Engineer, AK New Developments Form iDMS BF L DEC 7 200Li 10-404 Rev . Date December 02, 2001 Prepared by DeWayne R. $chnorr 564-5174~ SUBMIT IN DUPLICATE NS31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/02/2001 CONVERTED WELL FROM PRODUCING WELL TO MI GAS INJECTION WELL. 12/07/2001 MI GAS INJECTION RATE EVENT SUM MARY 12/02/01 CONVERTED WELL FROM PRODUCING WELL TO MI INJECTION WELL. 12/07/01 MI GAS INJECTION RATE - 70 MMSCFPD. FLUIDS PUMPED BBLS 0 NO FLUIDS PUMPED 0 TOTAL Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Add Perfs Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 1348' FSL, 649' FEL, Sec. 11, T13N, R13E, UM At top of productive interval 1995' FSL, 5090' FEL, Sec. 12, T13N, R13E, UM At effective depth 2026' FSL, 219' FWL, Sec. 12, T13N, R13E, UM At total depth 2034' FSL, 5046' FEL, Sec. 12, T13N, R13E, UM 5. Type of Well: Development __X Exploratory.__ Stratigraphic__ Service__ (asp's 659822, 6031120) (asp's 660646, 6031785) (asp's 660675, 6031817) (asp °s 660684, 6031825) 6. Datum elevation (DF or KB feet) RKB 56 feet 7. Unit or Property name Northstar Unit 8. Well number NS31 9. Permitnumber/approvalnumber 201-060 10. APInumber 50-029-23009 11. Field / Pool Northstar Unit 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface 11440 feet Plugs (measured) 11280 feet Intermediate Liner 11356 feet Junk (measured) 11197 feet Length Size Cemented Measured Depth True Vertical Depth 119' 20" Driven 244' 244' 3192' 13-3/8" 1534 sx PFE, 470 sx 'G' 3237' 3234' 10882' 9-5/8" 530 sx +Econolite 'G', 10927' 10774' 977 sx Class 'G' 658' 7" 190 sx Class 'G' 10781' - 11439' 10631' - 11280' Perforation depth: measured Open Perfs 11150'- 11170', 11184'- 11304' RECEIVED true vertical Open Perfs 10992'- 11012', 11026'- 11144' ~'C Tubing (size, grade, and measured depth) 7", 29#, 13 CR TBG @ 10730' MD. Tubing Tail @ 10785'. ~aska0JJ&G~Coos. Ooill[l~jssJol~a ~, ,__ Packers & SSSV (type & measured depth) 9-5/8" x 7" BAKER SABL-3 Packer @ 10730'. 7" HRQ SSSV @ 2037' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well opera 11/8/2001 Subsequent to op~ 11/20/2001 OiI-Bbl 4200 Representative Daily Avera.qe Production or Iniection Data Gas-Mcf Water-Bbl 9200 0 6420 14600 0 Casing Pressure Tubing Pressure 2222 2447 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __ 16. Status of well classification as: Oil _X Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. '~"~~~~~p Title: Sr Petroleum Engineer, AK New Developments """~'~%"~'~Michael Francis ~'~ ~ ~ ~ Date November 26, 2001 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE 11/18/2001 11/19/2001 11/18/O 1 11/19/01 NS31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PERF(ADD-PERF): PULL SSSV- DFF (PRE ADD PERFS) IN PROGRESS PERF(ADD-PERF): PERFORATE / RESET SSSV EVENT SUMMARY R/U S/L UNIT. RIH W/5.92" G-RING TO 2003' SLM. PULL 7" FXE SSSV @ 2003' SLM. RIH W/4.5" DUM GUN TO 11300' SLM (RKB TO BF = 15') ESTIMATED CORRECTED TD = 11315' MD. RIG DOWN S/L UNIT & R/U E-LINE UNIT. JOB IN PROGRESS, PERFORATE 11150-11170 W/TWO RUNS OF 10' 4.5" HSD PJ LOADED 5 SPF (ALL SHOTS FIRED ON BOTH RUNS). R/D E-LINE & R/U SLICKLINE. RUN IN HOLE WITH 7" FXE SSSV (SER# NS4-719780-01) AND SET AT 2003' SLM. GOOD CLOSURE TEST. R/D SLICKLINE. ****NOTIFY PAD OPER OF WELL STATUS**** FLUIDS PUMPED BBLS 3 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (3 TESTS) 3 TOTAL ADD PERFS 11/19/2001 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 4.5" HSD PJ LOADED 5 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 11150'-11170' Page 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O. Taylor ~ DATE: December 8, 2001 Chair ~ O fhr~~BJEcT: Mechanical Integrity Tests THRU: Tom Maunder ~ ~ ,, ePX Petroleum Engineer ~e,~.'~ ~ Northstar Island NS-31 PTD 2010600 FROM: Lou Grimaldi Northstar Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I Well] NS-31 I Typelnj. I G I T.V.D. I 10579 I Tubing I 4600 I 4600 I 4600 I 4600 [IntervalI I I P.T.D.I 2040600Imypetestl P I mestpsil 2~5 I CasingI 800 I 26801 27001 27001 P/F I --PI Notes: Standard Annullus test (Initial) I WellI NS-31 I Type,nj.I G I T.V.D. I ~0579 I Tubing 14600 14600 14600 14600 I lntervall I P.T,D.I 2010600ITypetestl P ITestpsil 2645 ICasingI 2700I 1740I 1745I 1745I P/F I -P Notes: Dropped I.A. pressure and observed for possible buildup Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details I travelled to Northstar island to witness the initial MIT on NS-31. The first attempts at the test failed and it appeared this well had a possible packer leak. Some troubleshooting performed by Mike Eagland (DHD tech.) produced a bad gauge. This caused the pressure to be shown as rising and falling on its own. A new gauge was rigged up and the test of this well showed passing results. M.I.T.'s performed: 1_ Attachments: None Number of Failures: None Total Time during tests: 6 cc: Anders/Yeager (BPX) MIT report form 5/12/00 L.G. MIT Northstar NS-31 12-8-01 LG.xls 12/10/01 Date: 12-06-2001 Transmittal Number:92353 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top SW Name Date Contractor Log Run 'Depth Bottom Depth Log Type NS31 11-19-2001 SCH 1 10700 11200 PERFORATION RECORD; ECEIVED Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Ken Lemley MB3-6 Attn: Tim Putnam MB3-6 Attn:' Buford Bates (Murphy Exploration) Attn: Howard Okland (AOGCC) Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box '196612 Anchorage, AK 99519-6612 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ PROD TO INJECT Alter casing _ Repair well _ Plugging _ CONVERSION Change approved program _ Pull tubing_ Re-enter suspended well _ CONVERT PRODUCER Time extension _ Stimulate _ TO INJECTOR Vadance _ Perforate _ Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~te, AK 99519-6612 4. Location of well at surface ,,~ ~ J~ 1348' FSL, 649' FEL, Sec. 11, T13N, R13E, UM At top of productive interval 1995' FSL, 5090' FEL, SEC 12, T13N, R13E, UM At effective depth 2026' FSL, 219' FWL, Sec. 12, T13N, R13E, UM At total depth 2034' FSL, 5046' FEL, Sec 12 T13N, R13E, UM 5. Type of Well: Development Exploratory _ Stratigraphic _ Service_ (asp's 659822, 6031120) (asp's 660646, 6031785) (asp's 660675, 6031817) (asp's 660684, 6031825) 6. Datum elevation (DF or KB feet) RKB 56.0 feet 7. Unit or Property name Northstar Unit 8. Well number NS31 9. Permitnumb~yapprovalnumber 201-060 10. APInumber 50-029-23009~ff 11. Field / Pool Northstar Unit 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 199' Surface 3192' Size 20" 13-3/8" Intermediate 10882' 9-5/8" Liner 658' 7" 11440 feet Plugs (measured) 11280 feet 11356 feet Junk (measured) 11197 feet Cemented Driven 1534 sx PFE, 470 sx 'G' 530 sx Econolite 'G', 977 sx Class 'G' 190 sx Class 'G' Measured Depth 244' 3237' 10927' 10781'-11439' True vertical Depth 244' 3234' 10774' 10631'-11280' Perforation depth: measured Open Perfs 11150' - 11170', 11184' - 11304' true vertical Open Perfs 10994' - 11014', 11027' - 11146' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 7", 29#, 13Cr TBG @ 10730' MD. Tubing Tail @ 10785' 9-5/8" x 7" BAKER SABL-3 Packer @ 10730'. 7" HRQ SSSV @ 2037' MD. RECEIVED NOV 0 2001 AIIIiIla 011 & Gas Cms. Co~m~o. 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch _ 15. Status of well classification as: 14. Estimated date for commencing operation 11/24/2001 16. If proposal was verbally approved Name of approver Date approved Oil _ X Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Michael Francis @ 564-4240. Signed /~l(f~ L,~- ~--?,"'b'~--~ Title: Senior Petroleum Engineer, AK New Developments Date November20,2001 Michael Fr~cis /./ ~ Prepared by DeWayne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ B~P Test _ Location clearance _ Mechanical Integrity Test X ~V,~ ~'.'3~ Subsequent form required 10- L~l,~t"~ Approved by order of the Commission Original Signed BY Cammy 0ec. hsli Form 10-403 Rev 06,15,88 · ORIGINAL Commissioner J Approval no. ,..~[ .--~ ~ Date ///~_ ~/ / / SUBMIT IN TRIPLICATE bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-$111 November 20, 2001 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for NS31 to Convert from Production to Injection BP Exploration Alaska, Inc. seeks permission to convert the NS31 well from a producer to an injector. This permission is being sought in advance to be prepared in case the current injection well, the NS29, must be taken out of service. Production operations at Northstar require a functional injection well for the miscible gas injection flood and as a means to avoid flaring. This conversion will not require any wellbore modifications. The 7", 29 Ib/ft 13Cr-80 tubing has a burst rating of 8160 psi. This exceeds the maximum anticipated injection pressure of 5300 psi by 54%. The USIT shows good cement across the 9-5/8" shoe to provide zonal isolation. Conversion will be accomplished through surface facility modifications. After this well has been converted and injection is established, a State Witnessed MIT will be performed. Please call (Mike Francis 564-4240, hm: 644-0534, cell: 529-8678, MichaeI.Francis@bp.com) if there are any questions. Sincerely, Michael J. Fr~.~E.. Alaska New ~elopments Senior Petroleum Engineer Background Data: Well: NS-31 APl' 50-029-23009-00 Tree: ABB-VGI 7" 6.5 ksi Tubing: 7" 13-Cr to 10785' MD Tubing Tail: NA - monobore __ SSSV Nipple: HRQ SVLN @ 2037' MD, 5.963" ID w/7" FXE SSSV (SER# NS4-719780-01)._ GLM: None Packer: Baker SABL-3 @ 10730' MD, 6.00" ID Min ID: 7" RN Nipple @ 10767' MD, 5.77" ID Surf Casing: 13-3/8" L-80 @ 3237' MD (68#/ft.) Intermed. Csg: 9-5/8" L-80 @ 10927' MD (53.5#/ft.) Prod Liner: 7" 13-Cr 10781-11439' MD, liner top ZXP packer, Flex Lock liner hanger PBTD: 11356' MD Max Deviation: 25 deg @ 8669' MD Max Dog Leg: 2.6 deg/100' @ 8385' MD Tubing Fluid: Production Fluids - Oil and Gas IA Fluid: Diesel to _+ 2900 ft MD, seawater below OA Fluid: Diesel to _+1900 ft MD, mud below Perforations: 11150 - 11170 MD (add perfs shot on 11-19-01 ) (20 ft) and 11184-11304' MD (original perfs) (120 ft); All 140' Perforated with Schlumberger 4.5" 4505 Power Jet, HMX; Penetration: 54", Hole: 0.42", SPF: 5, Phase: 72 deg phasing Reservoir Est. 5175 psi @ 11,100' TVD SS. EMW = 9.0 ppg Pressure: WH Pressure: The FTP is +/- 2,500 psi. When Shut-in, the SITP is 2,600 psi. The possible maximum pressure if well switched .out to all NS formation gas is 3760 psi. H2S ppm: none expected Current Status: Producing. This well will be converted to gas injection well later. TREE: ABB-VGI 7"~ WELLHEAD:ABB-VGI 13-5/8" 6.5 ksi Multibowl NS31 i ORIGINAL RT. ELEV = 55.77' RT/GL. ELEV =40.2' CB/MSL. ELEV = 15.67' SSSV @2037' MD 2034' TVD 7" HRQ SVLN 5.963" ID 13 3/8", 68#/ft, L-80, BTC @3237' __.6.8PPG DIESEL FREEZE PROTECTION AT +/- 2700 7", 29#/ft, 13Cr TUBING ID: 6.184" CAPACITY: 0.037 BBL/FT 7" R NIPPLE, @10709' 5.963" ID (OTIS) 7" R NIPPLE, @ 10755' 5.963" ID (OTIS) 7" RN NIPPLE, @10767' 5.77" ID (OTIS) 7" WLEG, @ 10785' 6.184" ID (OTIS) 9 5/8", 53.5#/ft L-80, BTC-M @ 10927' I:B= LCQ G~'A[]'(5~J01) /~N3_EAT~ I~'~ ~a. to I~o:t.c~ EBfer I~istcrical i:~rf data hitia I~f - O'erg~: 45C6 R:~verJ~, I-~ I:~a~cr[ 54"; 14.51 5 I 4.51 5 I 11150-11170' I 10~-11012 I q~n 1 11/193~011 PBTD @ 11356' MD 11195' TVD TD @ 11439' Baker SABL~3 PACKER 6.00" ID @10730' MD 10579' TVD 7" LINERTOP @10781' MD 10629' TVD 6.184" ID 7", 29#, 13Cr DATE 6/4/O 1 7/24/01 9/10/01 11/20/01 REV. BY AGK EMF COMMENTS Initial Diaqram Add Perf EMF Inserted TVD Depths EMF Add Perf Northstar WELL.. NS31 APl NO:50-029-23009-00 BP Exploration (Alaska) PUD DA/--: Casing: ~ ~' Shoe: ~5~ MD TVD, DV: MiD .T~-O Liner: ~ Shoe: %t~A~ MD T'~; TOP: ~q%~ l-m TVD . .wrCRA_NiC;_L ,_MTEGRIT_ PART ~ Cemenu Volumes:-Amt. Liner :ct~.~. ; Csg ~~.k ,; DV ~ . · Theoretical TOC Cement Bond Log (Yes or No) x'~Cc% ; In AOGCC File CBL Evaluation zone above perfs · Production Log: T~e ~ Evaluation CONCLUSIONS: Part fl: .°ar: ~2: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-060 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 l~l;J~'~'~ .................. 50-029-23009-00 4. Location of well at surface 1348'NSL, 649'WEL, SEC. 11 T13N, R13E, UM " i.,,': i! '~'~ ~ 9. Unit or Lease Name At top of productive interval ' ..~._._.~..: /_.. ii r~"~~' Northstar Unit 1978' NSL' 5115' WEL' SEC' 12' T13N' R13E' UM At total depth ii i ~' 10. Well Number 2034' NSL, 5051' WEL, SEC. 12, T13N, R13E, UM ..... 'Z".i ............ 7~::'... NS31 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Northstar Unit RKB = 56' ADL 312799 12. Date Spudded4/26/2001 113' Date I'D' Reached 114' Date C°mp'' Susp'' °r Aband'5/21/2001 7/3/2001 115' Water depth' if °ffsh°re39' M S L 116' N°' °f C°mpleti°nsO ne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 11440 11280 FTI 11356 11197 FTI []Yes []NoI (Nipple)2037' MDI 1545' (Approx.) 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, CNL, DEN, USIT, Sonic 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 169# X-56 Surface 199' 20" Driven 13-3/8" 68# L-80 45' 3237' 16" 1534 sx PFE~ 470 sx 'G' 9-5/8" 53.5# L-80 43' 10927' 12-1/4" 530 sx Econolite 'G'~ 977 sx Class 'G' 7" 29# 13Cr 10781' 11439' 8-1/2" 190 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 4--1/2" Gun Diameter, 5 spf 7", 29#, 13Cr 10785' 10730' MD TVD MD TVD 11184'. 11204' 11027'. 11047' , 11204' - 11244' 11047' - 11087' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. , 11244'- 11264' 11087'- 11106' DEPTH INTERVAL IUD) AMOUNT & KIND OF MATERIAL USED 11264'- 11284' 11106'- 11126' 10811' - 10816' Unable to circulate after landing 9-5/8" ' ' 11284' - 11304' 11126' - 11146' casing, Perf'd (4-1/2" Guns, 12 spf) to enable cementing of the 9-5/8" casing 2700' Freeze Protect with 160 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 31, 2001 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS'MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL'BBL GAS'MCF WATER'BBL OIL GRAViTY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~ Temporarily Suspended per S. McMains / B. Crandall - This well is completed but until facilities are functioning it will be shut in. A revised 10-407 will be submitted when production begins. ~:'~ ,-;~ ., Form 10-407 Rev. 07-01-80 .,~ t l u ..(;.ate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. SV6 3070' 3067' SV5 3337' 3334' SV4 3650' 3647' SV2 4056' 4053' SVl 4448' 4445' TMBK 4800' 4797' Schrader Bluff 6398' 6395' Kuparuk 8945' 8880' Kuparuk C 9055' 8982' Miluveach 9310' 9219' Sag River 10865' 10713' Shublik 10957' 10804' Ivishak 11065' 10910' Lisbu rne 11519' 11359' 1 '~:, (' I,~''~'~ I;i ' ~""-~ v ¢ ' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~ (~~ Title Technical Assistant Date NS31 201-060 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No./Approval No. , , , , ,, , , ,,, , ,, , , ~ ,,, , , , ,, , , , , , INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: ADD PERFS Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _X Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1348' FSL, 649' FEL, Sec. 11, T13N, R13E, UM At top of productive interval 1995' FSL, 5090' FEL, SEC 12, T13N, R13E, UM At effective depth 2026' FSL, 219' FWL, Sec. 12, T13N, R13E, UM At total depth 2034' FSL, 5046' FEL, Sec 12 T13N, R13E, UM 5. Type of Well: Development Exploratory __ Stratigraphic __ Service__ (asp's 659822, 6031120) (asp's 660646, 6031785) (asp's 660675, 6031817) (asp's 660684, 6031825) 6. Datum elevation (DF or KB feet) RKB 56.0 feet 7. Unit or Properbj name Northstar Unit 8. Well number NS31 9. Permitnumber/approvalnumber 201-060 10. APInumber 50-029-23009 11. Field / Pool Northstar Unit 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 199' Surface 3192' Size 20" 13-3/8" Intermediate 10882' 9-5/8" Liner 658' 7" 11440 feet Plugs (measured) 11280 feet 1.1356 feet Junk (measured) 11197 feet Cemented Driven 1534 sx PFE, 470 sx 'G' 530 sx Econolite 'G', 977 sx Class 'G' 190 sx Class 'G' Measured Depth 244' 3237' 10927' 10781'-11439' True vertical Depth 244' 3234' 10774' 10631'-11280' Perforation depth: measured Open Perfs 11184' - 11304' true vertical Open Perfs 11027' - 11146' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 7", 29#, 13Cr TBG @ 10730' MD. Tubing Tail @ 10785' 9-5/8" x 7" BAKER SABL-3 Packer @ 10730'. 7" HRQ SSSV @ 2037' MD. RECEIVED N0V 0 7 001 Alaska 0il & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch _ 15. Status of well classification as: 14. Estimated date for commencing operation 11/12/2001 16. If proposal was verbally approved Name of approver Date approved Oil _ X Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Michael Francis @ 564-4240. Sign ed (~ ~.~2~,,.-~.~ Title: Senior Petroleum Engineer, AK New Developments Date November 07, 2001 Michael F ncis ~',~,~ - FOR COMMISSION Vlichael F~ tis Prepared by DeWayne R. Schnorr 564-5174 USE ONLY Conditions of approval: Itrbtify Commission so representative may witness I Approval no.,~ i ' Plug integrity _ BOP Test _ Location clearance _ ,.,., Mechanical form _ Integrity Test_ Subsequent required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 · Original Signed By Cammy. 0echsli Commissioner Date SUBMIT IN TRIPLICATE BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 07, 2001 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for NS31 to Add Perfs (Ivishak) BP Exploration Alaska, Inc. proposes to add perforations because this well is producing below expectations. The calculated PI is 5 Bbl//tpsi compared to a PI of 14 Bbl/Apsi in the offset well, NS27. A petrophysical review shows the rock quality (permeability) at NS31 is about half that in NS27. Additional perforations in NS31 are proposed to offset this kh impairment and increase the productivity. The expected net oil benefit is 5,000 BOPD. The procedure includes the following major steps: IOR Type Work Desciption Slickline Pull SSSV, Drift/tag w/dummy gun 5,000 Electric Line Perforate 20' of Ivishak 11150 - 11170 MD, (10992' - 11012' TVD) Slickline Run SSSV Last Test: Max. Deviation: Perfs: Min. ID: Last TD tag: Last Downhole Ops: Latest H2S value: Reference Log: BHT & BHP: Nov 05, 2001 - BOPD 6865, Gas 15340, FTP 1709 psi. 25-0 @ 8669' md Deviation at perfs: 9-0 11184' - 11304' MD 5.77" at RN nipple @ 10767', see schematic 11356' MD. Drilling 05-29-2001 Stroke $SSV 10/09/01 0 PPM, none expected. Schlumberger GR/AIT May 22, 2001 250° F & 5175 psia @ 11100' TVDSS Please call (Mike Francis 564-4240, hm: 644-0534, cell: 529-8678) if there are any questions. Back~lround Data: Well: NS-31 APl' 50-029-23009-00 __ Tree: ABB-VGI 7" 6.5 ksi __ Tubing: 7" 13-Cr to 10785' MD Tubing Tail: NA - monobore __ SSSV Nipple: HRQ SVLN @ 2037' MD, 5.963" ID w/7" FXE SSSV (SER # 588927 - 1. NOTE: NO SECONDARY LOCKING DEVICE SENT W/SSSV) GLM: None Packer: Baker SABL-3 @ 10730' MD, 6.00" ID Min ID: 7" RN Nipple @ 10767' MD, 5.77" ID Surf Casing: 13-3/8" L-80 @ 3237' MD (68#/ft.) Intermed. Csg: 9-5/8" L-80 @ 10927' MD (53.5#/ft.) Prod Liner: 7" 13-Cr 10781-11439' MD, liner top ZXP packer, Flex Lock liner hanger PBTD: 11356' MD Max Deviation: 25 deg @ 8669' MD Max Dog Leg: 2.6 deg/100' @ 8385' MD Tubing Fluid: Production Fluids - Oil and Gas IA Fluid: Diesel to +- 2900 ft MD, seawater below OA Fluid: Diesel to +_1900 ft MD, mud below Perforations: 11184-11304' MD (120 ft); Perforated with Schlumberger 4.5" 4505 PowerJet, HMX; Penetration: 54", Hole: 0.42", SPF: 5, Phase: 72 deg Reservoir Est. 5175 psi @ 11,100' TVD SS. EMW = 9.0 ppg Pressure: WH Pressure: The FTP is +/- 2300 psi. When Shut-in, the SITP is 2600 psi. The possible maximum pressure if well switched out to all NS formation gas is 3760 psi. HaS ppm: none expected Current Status: Producing. This well will be converted to gas injection well later. Resources Scaffolding, crane, bleed trailer, Schlumberger crew, 20' of 4.5 inch Required: perforating guns. Wells Group PE to supervise. Material Diesel for lubricator testing Required: Waste Waste fluids to be manifested and pumped into disposal well NS-10 or into Disposal: the production manifold. Coordination: Many Simultaneous Operations, Coordinate w/NS Operations Manager 670- 3565 and Drilling 670-3565 Contacts: Mike Francis, Engineer 564-4240, cell 529-8678 Wells Group: Cismoski/Romberg 659-5584, pager 659-4236, pgr 124 Note: Northstar is a very sensitive area. All precautions should be taken to prevent spills of any kind during wellwork. Sincerely, I J. Fran[ci~, P.ET. Alaska New De~!lopments Senior Petroleum Engineer WELLHEAD:ABB-VGI RT/GL. ELEV =40.2' 13-5/8" 6.5 ksi Multibowl CB/MSL. ELEV = 15.67' HRQ SSSV @2037' MD 2034' TVD 7" HRQ SVLN 5.963" ID 6.8PPG DIESEL FREEZE PROTECTION AT +/- 2700 13 3/8", 68#/ft, ~,~ L-80, BTC @3237' 7", 29#/ft, 13Cr TUBING ID: 6.184" CAPACITY: 0.037 BBL/FT 7" R NIPPLE, @10709' 5.963" ID (OTIS) 7" R NIPPLE, @ 10755' ~ ~, Baker SABL-3 PACKER 5.963" ID (OTIS) - ~ 6.00" ID @10730' MD 10579' TVD 7" RN NIPPLE, @10767' 5.77" ID (OTIS) -'--"--'-- 7" WLEG, @ 10785' ~ _ 7" LINER TOP @10781' MD 6.184" ID (OTIS) 10629' TVD 6.184" ID 9 5/8", 53.5#/ft L-80, BTC-M @10927' ~,~ · FI~.CORA'TION SUMVlARY REF LOG: GR/AiT (5/22/01) ~e-ln Log: GR/CCL/USIT] ANGLE AT TOP lEI:F: Note: Fbfer to R'oduction DB for historical perf data hitial Perf - Charge: 4505 Power,Jet, HMX; Penetration: 54" Hole: .42"; Fhase: 72 de.q TD @11439' ~ · 7", 29#, 13Cr DATE REV. BY COMMENTS Northstar 6/4/01 AGK Initial Dia.qram ~ NS31 7/24/01 EMF Add Porf APl NO:50-029-23009-00 9/10/01 EMF Inserted TVD Depths BP Exploration (Alaska) bp Date: 09-06-2001 Transmittal Number:92138 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If you have any questions, please contact me in the PDC at 564-4091 SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type NS31 07-12-2001 SCH 1 10700 11350 PERFORATION RECORD; Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Ken Lemley MB3-6 Attn: Tim Putnam MB3-6 Attn: Buford Bates (Murphy Exploration) Attn: Howard Okland (AOGCC) ~ cf,a/ Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) RECEIVED SEP 1 0 ;)001 Alaska Oil & Gas Cons. Commis~on Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp Date: 08-02-2001 Transmittal Number:92190 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If you have any questions, please contact me in the PDC at 564-4091. q I Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type NS13 06-16-2001 SPERRY I 199 11490 FORMATION EVALUATION MUDLOG; 1:600 SCALE (MD) NS13 06-16-2001 SPERRY 1 199 11490 FORMATION EVALUATION MUDLOG; 1:600 SCALE (TVD) NS13 06-16-2001 SPERRY I 199 11490 FORMATION EVALUATION MUDLOG; 1:240 SCALE (MD) NS13 06-16-2001 SPERRY I 199 11490 FORMATION EVALUATION MUDLOG; 1:240 SCALE (TVD) NS31 05-21-2001 STATE OF - - - WELL COMPLETION ALASKA REPORT NS29 06-18-2001 STATE OF WELL COMPLETION ALASKA - - - REPORT; NS13 06-16-2001 SPERRY END OF WELL REPORT; . . ~S13 06-16-2001 SPERRY I 199 11490 FORMATION EVALUATION MUDLOG; (DISKETTE) Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center RECEIVED AUG 0 ?_ 2001 Attn: Ken Lemley MB3-6 Attn: Tim Putnam MB3-6 Attn: Buford Bates (Murphy Exploration) Attn: Howard Okland (AOGCC) Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) ~ Oil & Gas Cons. Commilgion Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMissION WELL COMPLETION OR RECOMPLETION REPORT AND LOG REVISED: 07127/01 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service [] TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-060 ~..L~ ~ o 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23009-00 4. Location of well at surface ' ,:;:5:.. i: ~ ~.~i, ~ ~,~?.~ , "r~ · '9. Unit or Lease Name 1348' NSL, 649' WEL, SEC. 11, T13N, R13E, UM Northstar Unit At top of productive interval .Z'_, ,~' ~ : ' ....... -' -:/..- [.L~ '-~ o 1995' NSL, 5090' WEL, SEC. 12, T13N, R13E, UM .,' '.~:. At total depth .,o/.~ ' 10. Well Number NS3 2034' NSL, 5046' WEL, SEC. 12, T13N, R13E, UM .~ .. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Northstar Unit RKB = 56' ADL 312799 12. Date Spudded4,26,2001 113' Date T'D' Reached 114' Date c°mp'' susp'' °r Aband'5/21/2001 7/3/2001 115' water depth' if °ffsh°re39' MSL 116' N°' °f c°mpleti°nsone 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+'rVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 11440 11280 FTI 11356 11197 FTI []Yes [] NoI (Nipple) 2037' MDI 1545' (Approx.) 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, CNL, DEN, USIT, Sonic 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 169# X-56 Surface 199' 20" Driven 13-3/8" 68# L-80 45' 3237' 16" 1534 sx PFE, 470 sx 'G' 9-5/8" 53.5# L-80 43' 10927' 12-1/4" 530 sx Econolite 'G'I 977 sx Class 'G' 7" 29# 13Cr 10781' 11439' 8-1/2" 190 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. ' TUBING RECORD Bottom and interval, size and number) sizE 'DEPTH SET (MD) .... PAcKEF{ SET (MD) 4--1/2" Gun Diameter, 5 spf 7", 29#, 13Cr 10785' ' ...... 10730" ...... MD TVD MD TVD ........................... 11184'- 11204' 11027'- 11047' '26. . AciD, FRACTURE, CEM'ENT SQuEEzE, ETC. " 11204'- 11244' 11047'- 11087' 11244'- 11264' 11087'- 11106' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11264' - 11284' 11106' - 11126' 10811' - 10816' 'Unable to circulate after landing 9-5/8" 11284' - 11304' 11126' - 11146' casing, Perf'd (4-1/2" Guns, 12 spf) to enable cementing of the 9-5/8" casing 2700' Freeze Protect with 160 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · Temporarily Suspended per S. McMains / B. Crandall - This well is completed but until facilities are functioning it will be shut in. A revised 10-407 will be submitted when production begins. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. SV6 3070' 3067' SV5 3337' 3334' SV4 3650' 3647' SV2 4056' 4053' SV1 4448' 4445' TMBK 4800' 4797' Schrader Bluff 6398' 6395' KuparukMiluveach 8945'9310, 8880'9219, ,,,~,,~,~/~,.~,%,,.,. ~~' Kuparuk C 9055' 8982' Sag River 10865' 10713' ,~.. Shublik 10957' 10804' (~- Ivishak 11065' 10910' 31. List of Attachments:' Summary of Post Rig Operations ........................................ 32. I hereby certify that the fore. goi'ng is .... ct to t'h'e best of' my, kn0wl~dge ..................................................................... .Signed 'rerrieHubb,e.~~~,,., ...... Ti.tie TechnicalAssistant, , ,Date 0~7,~,"~,(~../.. NS31 201-060 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. /Approval No. INSTRUCTIONS (~ENERAL'- This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, Steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM ,5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORi61NAL Well: NS31 Field: Northstar Unit APl: 50-029-23009-00 Permit: 201-060 POST - RIG WORK 07/02/01 MIRU Slick line, RIH with 7" GS pulled dummy SSSV at 1995 SLM, POOH. RIH with Bell Guide / Pulling tool, pull B&R at 10640' SLM. RIH with 7" GS pull plug, on 3rd attempt from 10643' SLM. RIH with 4.5" Dummy gun. Tag at 11327' SLM, RDMO. 07/03/01 MIRU Wire line, RIH with USIT, Log USIT from 11350' ELM to 10800' ELM. Good Cement from 11350' to liner top. RIH with 4.5", 20' HSD gun, tie in and shoot gun from 11284' -11304' WHP increased from 0 PSI to 650 PSI after gun was shot. POOH while pumping Diesel to freeze protect. 07/05/01 MIRU, Wire line, RIH with 4.5" 20' HSD perforating gun. Log down while RIH with Collar Iocator, log pass jewelry CCL working. Log up for tie in pass at 10900' across jewelry, Collar Iocator not reading correctly, POOH, CCL full of metal fillings. Rig down Wire line. 07/12/01 & 07/13/01 Gun one perforation interval 11264'- 11284' (4-1/2" PJ HSD Guns /5SPF). Locate fluid interface at 2830' bottom of Diesel and 2973' top of seawater. (PSP-GRADIO) Gun two interval 11244'- 11264'. Winch problems encountered unable to POOH. T-Bar off cable at 9650' and wait on SWS mechanic. Repaired Winch motor right angle drive. Perforated interval 11204' - 11244' with 4-1/2" power jet HSD Guns / 5SPF - 72 Degrees random. WHP jumped when shooting guns, but remained 600 PSI between runs. 07/14/01 RIH with Gun #6 shot 11184' to 11204' with 4-1/2" HSD/5 SPF Power Jet, POOH. 07/15/01 Made several runs with various tools and successfully fished BPV and Running Tool from tree. Secured Well, will re-run BPV at later date. 07/17/01 Brush and Flush BPV and SSSV nipples, set SSSV and perform closure test, set BPV and Test. Tree Cap installed and tested. bp Date: 06-26-2001 Transmittal Number:92182 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If you have any questions, please contact me in the PDC at 564-4091. Top SW Name Date Contractor Loll Run Depth Bottom Depth Loll Type NS31 04-26-2001 SCH 1-4 132.44 10891.09 COMPOSITE FINAL PRINT; CDR; NS31 04-28-2001 SCH 1-4 6600 10900 COMPOSITE FINAL PRINT; ~AND; NS29 06-18-2001 SCH 1 13000 13667 PERFORATING RECORD; NS13 06-28-2001 SCH 1 200 9950 GEOFRAME PROCESSED INTERPRETATION; QC PLOT-DSI; SONIC PROCESSING; NS31 05-12-2001 SCH 1 198.0 10945.00 LWD;AND;CDR; (CD) Zot,.o%I° rn one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center RECEIVF_'D JUL 2 6 20t)1 0il & Gas Cons. Commmion ~chorage Attn: Ken Lemley MB3-6 Attn: Tim Putnam MB3-6 Attn: Buford Bates (Murphy Exploration) Atm;:.go,,w,.ard~ 0~and (AOGCC) ' Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Date: 06-25-2001 Transmittal Number:92179 BPXA WELL DATA TRANSMITTAL Please replace the log sent to you previous with this one. This is a reissue to include the dt stonely from the dipole sonic tool, sorry for any inconvenience. This data is being sent separate because of the confidential nature. If you have am uestions, please contact me in the PDC at 564-4091 ~SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type ULTRASONIC IMAGER; NS31 07-03-2001 SCH I 10700 11350 JEWELRY LOG; MODULAR DYNAMIC NS31 05-25-2001 :SCH 1 10964 11402 FORMATION TESTER; Thank You, James H. Johnson Petrotechnical Data Center Attn: Ken Lemley MB3-6 Attn: Tim Putnam MB3-6 Attn: Buford Bates (Murphy Exploration) At'tn:': How ardOkl and ,( AOGCC)~' Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) RECEIVED JUL 2 6 ;7001 Alaeka Oil & Gas Cons. Commi~mion Petrotechnical Data Center LR2~ 1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp Date: 07-11-2001 Transmittal Number:92170 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If you have aw, uestions, ~lease contact me in the PDC at 564-4091 Top Bottom 'SW Name Date Contractor Log Run Depth Depth Log Type IMUDLOG DATA; NS31 06-14-2001 SCH 1 0 11278 'DISKETTE; (1EA) Please Sign and Returfi one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Ken Lemley MB3-6 Attn: Esther Fueg MB3-6 Attn: Buford Bates (Murphy Exploration) Attn: Howard Okland (AOGCC) Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp Date: 07-11-2001 Transmittal Number:92168 CONFIDENTIAL BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If you have an,. questions, please contact me in the PDC at 564-4091 Top Bottom SW Name Date Contractor Log Run Depth Depth Log Type PLATFORM EXPRESS; COMPENSATED NEUTRON LOG; NS31 05-22-2001 SCH 1 10953 11460 LITHODENSITY LOG; DIPOLE SHEAR SONIC NS31 05-22-2001 SCH 1 10953 11460 IMAGER; NS31 05-22-2001 SCH 1 10953 ~11460 ARRAY INDUCTION LOG; HIGH RESOLUTION NS31 05-22-2001 SCH I 10953 11460 LATEROLOG; PLATFORM EXPRESS; NS31 05-22-2001 SCH I 10953 11460 SSTVD LOG; COMBINABLE MAGNETIC NS31 05-22-2001 SCH 1 10953 11460 RESONANCE LOG; PRIMARY DEPTH CONTROL GAMMA RAY; NS31 05-22-2001 SCH 1 980.00 11460.00 (CD) Please ~ign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Ken Lemley MB3-6 Attn: Esther Fueg MB3-6 Attn: Buford Bates (Murphy Exploration) Attn: Howard Okland (AOGCC) Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 RECEIVED JUL 11 Anti.ge bp Date: 07-09-2001 Transmittal Number:92165 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If you have an' questions, please contact me in the PDC at 5644091 . - Top Bottom SW Name Date Contractor Log Run:Depth Depth LogType DIPOLE SHEAR SONIC NS29 06-05-2001 SCH I 4800 13666 IMAGER; PLATFORM EXPRESS; NEUTRON POROSITY NS29 06-05-2001 SCH I 4800 13666 LOG; NS29 06-05-2001 SCH I 4000 13666 ULTRA SONIC IMAGER; UST/DSI/CNL/GYRO; STANDARD SONIC NS29 06-05-2001 SCH I 4730 13630 PROCESSING; CASED HOLE EDIT; NS29 06-27-2001 SCH I 4730 13664 DSI/CNT;(CD) ULTRASONIC COLLAR; NS29 06-05-2001 SCH 1 0 13656 GAMMA RAY LOG;, NS31 05-22-2001 SCH 3, 4 6800 10800 LWD ISONIC; WELL COMPLETION NS31 06-01-2001 STATE - - - REPORT; .ol- oql Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Ken LemleY MB3-6 Attn: Esther Fueg MB3-6 Attn: Buford.Bates (Murphy Exploration) Attn: Howard Okland (AOGCC)' Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) RECEIVED 'JUL 0 9 2001 Alalllm Oil a Gas Cons. C°mm~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp CONrlDr TIAL Date: 06-26-2001 Transmittal Number:92152 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If you have any questions, please contact me in the PDC at 564-4091. Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type NS31 04-26-2001 SPERRY 1,2,3,4 0 11,440.00 FORMATION EVALUATION MUD LOG; (2" MD) NS31 04-26-2001 SPERRY 1,2,3,4 0 11,272.00 FORMATION EVALUATION MUD LOG; (2" TVD) NS31 04-26-2001 SPERRY 1,2,3,4 0 11,440.00 FORMATION EVALUATION MUD LOG; (5" MD) NS31 04-26-2001 SPERRY 1,2,3,4 0 11,278.00 FORMATION EVALUATION MUD LOG; (5" TVD) NS31 05-22-2001 SCH I 8450 11450 BESTDT* FINAL RESULT; SONIC LOG; NS31 04-26-2001 SPERRY END OF WELL REPORT; . ~R~ttal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Ken Lemley MB3-6 Attn: Tim Putnam MB3-6 Attn: Buford Bates (Murphy Exploration) Attn: Howard Okland (AOGCC) Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) RECEIVED JUN 2 7 2001 Alal~0il&GasCoas.~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp Date: 06-20-2001 Transmittal Number:92146 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. SW Name Date Contractor Locj Run Top Depth Bottom Depth Log Type NS31 05-15-2001 SCH I 5980 10836 ULTRASON lC IMAGER CEMENT ,7,,~.t.-Ob~ LOG; NS31 05-22-2001 SCH I 10950 11300 CMR; CONFIDENTIAL Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petr°technical Data Center Attn: Ken Lemley MB3-6 Attn: Tim Putnam MB3-6 Attn: Buford Bates (Murphy Exploration) Attn: Howard Okland (AOGCC) Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) R :r'.EIVEP .mu 2 2. 01 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp CONriD£NTIAL Date: 06-19-2001 Transmittal Number:92141 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If you have any questions, please contact me in the PDC at 564-4091 SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type 2,ol - oq I GYRODATA SURVEY; GYRODATA;(DISKETTE;) NS29 06-05-2001 GYRODATA - 0 10976.07 .~oto0~ GYRODATA SURVEY; GYRODATA;(DISKETTE;) NS31 05-21-2001 GYRODATA - 0 11206.20 ~d Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Ken Lemley MB3-6 Attn: Tim Putnam MB3-6 Attn: Buford Bates (Murphy Exploration) Attn: Howard Okland (AOGCC) Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) RE(".;tVED JUN 2. "'. 2001 Ancllorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 i:~i' STATE OF ALASKA i ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well "' [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-060 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23009-00 4. Location of well at surface , , ~:~ ~.~..,.~, "~'~~ ~ 9. Unit or Lease Name 1348' NSL, 649' WEL, SEC. 11, T13N, R13E, UM At top of productive interval 1995' NSL, 5090' WEL, SEC. 12, T13N, R13E, UM At total depth i ..... ~ ..... i 10. Well Number .......... ~ NS31 2034' NSL, 5046' WEL, SEC. 12, T13N, R13E, UM : ........ ~ ....................... 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Northstar Unit RKB = 56' ADL 312799 12. Date Spudded4/26/2001 113' Date T'D' Reached 114' Date C°mp"-Susp" °r Aband' 115' Water depth' if Offs'h'Ore 116' N°' Of COmpleti°ns5/21/2001 6/~001 ~ 39 MSLI One 17, Total Depth (MD+TVD) 118. Plug Back Depth (MD+TV•) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 11440 11280 FTI 11356 11197 FTI •Yes r-INoI 2037'MDI 1545'(Approx.) 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, CNL, DEN, USIT, Sonic 23. CASING, LINER AND CEMENTING RECORD ,, , ,, , , , CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED ,, 20" 169# X-56 Surface 199' 20" Driven 13-3/8" 68# L-80 45' 3237' 1.6" 1534 sx PFE, 470 sx 'G' 9-5/8" 53.5# L-80 43' 10927' 12-1/4" 530 sx Econolite 'G', 977 sx Class 'G' , 7" 29# 13Cr 10781' 11439' 8-1/2" 190 sx Class 'G' ,, ,, , ................... , , 24. Perforations op. en to. Producti.on (M.D+,TVD of Top and 25. TUBING RECORD Bottom and imervah size uno number) SIZE DEPTH SET (MD) PACKER SET (MD) None 7", 29#, 13Cr 10785' 10730' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10811' - 10816' Unable to circulate after landing 9-5/8" casing, Perf'd (4-1/2" Guns, 12 spf) to enable cementing of the 9-5/8" casi"~ 2700' Freeze Protect with 160 Bbls of Diesel 27. PRODucTION TEST , , Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apParent dips and presence of oill gas Or'water. Submit core chips. *Temporarily Suspended per S. McMains/B. Crandall - This well is completed but until facil~r~i~4~rl~.i,~irj~be shut in. A revised 10-407 will be submitted when production begins. JUN ]. 3 ;~001 Form 10-407 Rev. 07-01-80 ORIgiNAL Anchorage Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. SV6 3070' 3067' SV5 3337' 3334' SV4 3650' 3647' SV2 4056' 4053' SV1 4448' 4445' TMBK 4800' 4797' Schrader BLuff 6398' 6395' Kuparuk 8945' 8880' KUparuk C 9055' 8982' Miluveach 9310' RECEIVED Sag River 10865' 10713' Shublik 10957' 10804' J UN ~_ 3 ~ 0 01 Ivishak 11065' 10910' Alaska Oil & Gas Cons. Commission Lisbu rne 11519' 11359' Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak Off Test 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble.~/j~,.~ (~~-~. Title Technical Assistant Date ~)6"'[~. '~/ , NS31 201-060 Prepared By Name/Number: Sondra Stewrnan, 564-4750 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL; This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: NS31 Common Name: NS31 I: SUrfaCe Pressure Leak Off Pressure (BHP) EMW 5/2/2001 LOT 3,237.0 (ft) 3,233.0 (ft) 9.30 (ppg) 1,020 (psi) 2,582 (psi) 15.37 (ppg) 5/20/2001 FIT 10,923.7 (ft) 10,776.8 (ft) 10.20 (ppg) (psi) 5,710 (psi) 10.20 (ppg) 5/28/2001 Press Test (ft) (ft) 9.30 (ppg) 3,540 (psi) 3,540 (psi) 9.30 (ppg) Printed: 6/4/2001 1:24:32 PM BP EXPLORATION Page i of 23 Operations Summa Report Legal Well Name: N831 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 4/25/2001 16:00 - 17:00 1.00 MOB P PRE Prep for Rig Move. 17:00 - 18:00 1.00 MOB P PRE PJSM and Lunch 18:00 - 19:30 1.50 MOB P PRE PJSM -- Unplug 1380v cable. 19:30 - 20:30 1.00 MOB P PRE Move Rig f/NS29 and NS31 20:30 - 22:30 2.00 MOB P PRE PJSM -- Chink Cellar and Set BOP back and secure. Free up bridgecrane to install riser sections. 22:30 - 23:30 1.00 MOB P PRE Set Lower Riser Section 23:30 - 00:00 0.50 MOB P PRE Install Mousehole and prep upper riser section. 4/26/2001 00:00 - 03:00 3.00 MOB N HMAN PRE NU upper section of scoping riser. Realize that upper and lower section of riser are misaligned and unable to seal upper flange and lower clamp assembly. Note: Rig is off center from well center 2" to the west. Unsuccessful in attempts to cinch up on turnbuckles and align diverter -- must realign rig. Discuss options. 03:00 - 03:30 0.50 MOB N HMAN PRE Pull upper section of riser. 03:30 - 05:00 1.50 MOB N HMAN PRE Inspected rig floor for skidding capability versus the modifications and possible damage -- determined no risk of damage. Held PJSM: Wrote prejob procedure and performed hazard risk mitigation for skidding rig floor. 05:00 - 06:30 1.50 MOB N HMAN PRE Lessen 9 bolts removing 2. Skidded rig floor 3" to east toward pipe rack. Tigthten 7 bolts. 06:30 - 10:00 3.50 RIGU P PRE Reinstalled upper section of scoping riser, nippled up, and connect flowline. 10:00 - 11:30 1.50 RIGU P PRE PU 13-3/8" mandrel landing hanger and 13-3/8" ianding joint. Drift diverter and land hanger in landing ring -- confirm measurment 45.15' RKB. 11:30 - 12:00 0.50 RIGU N HMAN PRE POOH with 13-3/8" mandrel landing hanger. Caught hanger on bottom end of upper riser section and curled lip. Finish POOH with landing joint and mandrel hanger. 12:00 - 13:00 1.00 RIGU N HMAN PRE Pull Riser for Repair. 13:00 - 13:30 0.50 RIGU P PRE Perform Diverter Test. 13:30 - 14:30 1.00 RIGU N HMAN PRE Reinstall upper riser section and reconnect flowline. 14:30 - 15:00 0.50 DRILL N HMAN SURF Redrift stack with 13-3/8" mandrel casing hanger. 15:00 - 17:00 2.00 DRILL P SURF Perform Electrical PM on Top Drive. 17:00 - 20:30 3.50 DRILL P SURF MU BHA. Change out jars and PU 3 joints of HWDP (rabbit). 20:30 - 21:00 0.50 DRILL P SURF Flowtest Shakers at 800 gpm -- good. 21:00 - 21:30 0.50 DRILL P SURF Cleaning out ice in 20" conductor f/55' to 134' md. 21:30 - 22:30 1.00 DRILL P SURF Blowdown, standback one stand of HWDP and MU remainder of rotary cleanout BHA. 22:30 - 23:00 0.50 DRILL P SURF Continue cleaning out 20" conductor f/134' to 199' md. Spud while drilling from 199' to 231' md. 23:00 - 00:00 1.00 DRILL P SURF Circulate hole clean, PJSM -~ RU wireline for gyro. 4/27/2001 00:00 - 01:00 1.00 DRILL P SURF PJSM -- Run Gyro Survey at 20" conductor shoe Note: .4 deg incl & 22.3 deg azimuth -- good deal! 01:00 - 02:30 1.50 DRILL P SURF LD rotary cleanout BHA. 02:30 - 06:00 3.50 DRILL P SURF PU Dir BHA, Orient MWD & Motor, RIH to Clean out depth. Note: 231' md is 32' openhole below conductor -- this is first time in 5 wells there has not been fill. 06:00 - 07:00 1.00 DRILL P SURF Drilled ahead to 315' md -- Drag Chain Link broke in two places. Circulate hole clean. 07:00 - 10:00 3.00 DRILL N SFAL SURF Repair Drag Chain -- chain links are severly worn on the side facing outward -- looking at solutions (see remarks). 10:00 - 11:30 1.50 DRILL P SURF Rotary Drlg f/231' to 463' to kick off point. Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 2 of 23 Operations Summa Report Legal Well Name: N831 'Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 4/27/2001 10:00 - 11:30 1.50 DRILL P SURF Note: Since conductor was vertical and oriented toward planned kickoff point, decision was made to drill ahead to kickoff point before gyro survey to save rig time. 11:30 - 13:00 1.50 DRILL P SURF Circulate hole clean while holding PJSM -- Run Gyro Survey Note: 0.7 deg incl & 88.5 deg azimuth -- excellentl! 13:00 - 13:30 0.50 DRILL P SURF Drlg in build section f/463' to 555' md. Slide Notes: 15' f/460' to 475' and 22' f/478 to 500'. 13:30 - 14:30 1.00 DRILL P SURF Circulate hole clean while holding PJSM -- Run Gyro Survey. 14:30 - 16:00 1.50 DRILL P SURF Drlg in build section f/555' to 646' md. Slide Notes: 20' f/552' to 572' and 20' f/597' to 617'. 16:00 - 17:00 1.00 DRILL P SURF Pump Sweep & circulate hole clean while holding PJSM -- Run Gyro Survey. 17:00 - 17:30 0.50 DRILL P SURF Drlg in build section f/ 646' to 736' md. Slide Notes: 15' f/644' to 659' and 15' f/689' to 704'. 17:30 - 18:30 1.00 DRILL P SURF Pump Sweep & circulate hole clean while holding PJSM -- Run Gyro Survey. 18:30 - 19:30 1.00 DRILL P SURF Drlg in build section f/ 736' to 828' md. Slide Notes: 19' f/734' to 753' and 20' f/784' to 804'. i 19:30 - 20:30 1.00 DRILL P SURF Pump Sweep & circulate hole clean while holding PJSM -- Run Gyro Survey. 20:30 - 00:00 3.50 DRILL P SURF Drlg in build section f/828' to 1194' md. Slide Notes: 20' f/825' to 845', 20' f/875' to 895', 25' f/916' to 941 ', 25' f/974' to 999, 25' f/1008' to 1033'. 4/28/2001 00:00 - 01:30 1.50 DRILL P SURF Pump Sweep & circulate hole clean while holding PJSM -- Run Gyro Survey of 5.03 degrees and 90.71 degree azimuth to confirm MWD survey of 5.21degree inclination and 91.16 degree -- check shot survey performed at 1026' md. 01:30 - 12:00 10.50 DRILL P SURF Drlg f/1194' to 2330' md. 12:00 - 15:00 3.00 DRILL P SURF Drlg f/2330' to 2613' md. Note: ! 1) Lost 75 bbls of drilling fluid while drilling @ 2474'. Shut down pumps and observe well during connection. 2) Losing ~1 bpm while circulating at full drilling rate ~710 gpm. 15:00 - 15:30 0.50 DRILL P SURF Pump Hi Vis Sweep with Barafibre while pumping surface to surface at full rate ~710 gpm. Adding barafibre while circulating. 15:30 - 22:00 6.50 DRILL P SURF Drlg f/2613' to surface hole TD @ 3249' md. Note: Added 130 Sxs Barafibre while drilling ahead. Losses reduced and ceased by TD. 22:00 - 00:00 2.00 DRILL P SURF Circulate and Condition Mud while reducing YP f/30+ to 27. Notes: 1) Checked Gels @ 10s/10m/30m & measured 14/19/23 respectively -- gels are not progressive. Mud is in good shape to run casing. 2) Cuttings cleaned up noticably -- shakers much cleaner at 2xBU. 3) Plan to continue to circulate during tour change and while morning tour holds prejob for POOH with drill pipe. 4) Zero losses while Circ and Cond. 4/29/2001 00:00 - 01:00 1.00 DRILL P SURF Circulate and Condition mud, observe well -- static. Pump dry Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 3 of 23 Operations Summa Report Legal Well Name: N831 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 4/29/2001 00:00 - 01:00 1.00 DRILL P SURF job. 01:00 - 03:00 2.00 DRILL P SURF POOH while evaluating hole condition for possibly eliminating the wiper trip and instead POOH to run casing. Notes: 1) Hole relatively problem free until tight area at top of permafrost ~1100. Pulled ~45K overpull and necessary to wipe. Stacked up solid @ 1080' md on two attempts to wipe HWDP stand #1 -- 3rd attempt broke through and fourth attempt wipe with no problem. 2) Pulled HWDP stand 2 with about 25K overpull -- wiped and pulled again with no overpull tp 887' md. 3) RIH with HWDP stands 9 and 8 as well as DP stands 1, 2 and 3 tp 1390' md. 4) POOH with the 3 stands of DP and 2 stands of HWDP f/ 1390' to 887' with 5 - 10K max overpulh 03:00 - 04:00 1.00 DRILL P SURF POOH f/887' to 190' md with maximum overpull of 5 to 10 K. 04:00 - 04:30 0.50 DRILL P SURF Hold PJSM for laying down BHA. 04:30 - 07:30 3.00 DRILL P SURF LD Directional BHA. Stabilizers had large amounts of clay but it was easily removed. 07:30 - 08:00 0.50 DRILL P SURF Clean up rig floor of tools and assessories. 08:00 - 09:00 1.00 DRILL N HMAN SURF Dropped Rubber Mat downhole while cleaning clayballs off stabilizers. I Note: A large chunk of clay fell onto a 2-1/2' square rubber mat that was being used to cover the hole. The rubber mat dropped past the rotary into the top of the riser and sunk out of sight into the mud. Attempts to retrieve the rubber mat were unsuccessful. RIH with 2 stands of dp to the 20" shoe and circulated 8000 strokes at 800 gpm with no success. Visually inspected flowline and removed flange in flowline to get better view. 09:00 - 11:00 2.00 CASE P SURF PJSM -- RU casing running equipment. Drain stack and inspect for rubber mat -- did not find it. 11:00 - 12:00 1.00 CASE P SURF PJSM for running casing -- MU float track --bakerlocked to pin end on joint 3. 12:00 - 13:00 1.00 CASE P SURF RU Frank's circulating tools, engage the element and circulate thru float equipmen -- ggod testt. 13:00 - 19:30 6.50 CASE P SURF RIH with 76 joints of 13-3/8" 68# L80, btrc. 19:30 - 20:30 1.00 CASE P SURF Work thru tight spot with joint 77 at 3087' md which correlates to the SV6 clay formation. Attempt to engage the Frank's Tool and circulate -- Frank's tool plugged -- RD Franks tool. 20:30 - 21:00 0.50 CASE P SURF Finish running last two casing joints 78 and 79. 21:00 - 21:30 0.50 CASE P SURF MU Mandrel Casing Hanger. 21:30 - 22:00 0.50 CASE P SURF MU Landing Joint and land casing hanger. ,22:00 - 22:30 0.50 CASE P SURF RU Crossover and Cementing Head. !22:30 - 00:00 1.50 CEMT P SURF Gradually establish circulation as per outline: 1) Increase rate by 1/2 bpm per 10 min until 3 bpm attained. 2) Increase rate by 1 bpm per 10 rain until 10 bpm attained. Note: Decision not to reciprocate based on rubber mat in hole and possible interference with landing mandrel casing hanger as well as concerns about scraping off LCM across loss zone with collar. 4/30/2001 00:00 - 01:30 1.50 CEMT P SURF Continue to circulate in prepartion to pump first stage 2 Stage cement job. (Held PJSM for 1st Stage of 2 Stage cement job.) Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 4 of 23 Operations Summary Report Legal Well Name: NS31 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 4/30/2001 00:00 - 01:30 1.50 CEMT P SURF Notes: Increase rate at 1/2 bpm per 10 min until 3 bpm attained. Increase rate at 1 bpm per 10 min until 10 bpm attained. 01:30 - 03:00 1.50 CEMT P SURF Pump 1st Stage of 2 Stage Cement Job. Notes: Drop bottom plug, Test lines to 3500 psi, Load top plug. Mix and Pump as follows: 75 bbls Alpha spacer, 95 bbls (470 sx) of Permafrost E Cmt and 96 bbls ( 470 sx) Premium G Cmt. Displace with rig and bump plug with 483 bbls (97% eft. factor) Bump plug with 1000 psi. 03:00 - 03:30 0.50 CEMT P SURF Bleed press and check floats -- OK. Preparation for Stage 2: Load Closing Plug for ES Cementer in Cement Head. Press and open ES Cementer @ 2300 psi pumping 3 bpm. 03:30 - 08:30 5.00 CEMT P SURF Circulate through ES Cementer@ 10 bpm. (Held PJSM for Stage 2 of cement job.) 08:30 - 11:00 2.50 CEMT P SURF Mix and Pump 2nd Stage of Cement Job as follows: 75 bbls Alpha spacer, 411 bbls (1064 sx) of Permafrost E Cmt Continued to pump cement until cement returns (cmt with red . dye and PH were witnessed at surface). . Displace with rig and bump closing plug with 240 bbls (97% eft. :factor) -- Thick clabbored cement returns to surface at ~120 bbls into displacement. 'Increase pressure and close ES Cementer with ~1400 psi-- !Increase pressure to 1900 psi -- hold to ensure no leaks. !Release pressure and check for backflow -- none. ' 11:00 - 12:00 1.00 CEMT P SURF RD cement head and elevators. Pull Landing joint. Flush and i drain stack. BIowdown cement and mud lines. 12:00 - 13:00 1.00 CEMT P SURF Lay down landing joint and change out bails. I 13:00 - 14:00 1.00 CEMT P SURF RU jetting tool (perforated pipe) and flush cement out of hanger, diverter bag and riser with mud pumps. 14:00 - 15:00 1.00 CEMT P SURF BIowdown all lines and clean rig floor. 15:00 - 18:30 3.50 CEMT P SURF ND riser and diverter. 18:30 - 21:30 3.00 CEMT P SURF Clean Cellar and Make Up Speed head (Csg & Tbg Spool Assy). 21:30 - 00:00 2.50 CEMT P SURF PJSM -- NU BOPE. 5/1/2001 00:00 - 00:30 0.50 DRILL P INT1 PJSM for NU BOP's 00:30 - 04:00 3.50 DRILL P INT1 N/U BOP's 04:00 - 04:30 0.50 DRILL P INT1 PJSM for Testing BOP's 04:30 - 11:30 7.00 DRILL P INT1 M/U test plug and fill stack. Test BOP's and Choke Manifold as per BP policy. Pull test plug. Run wear ring. Blow down choke and kill lines. 11:30 - 12:00 0.50 DRILL P INT1 PJSM for Making up BHA #3 12:00 - 13:00 1.00 DRILL P INT1 Make up BHA 13:00 - 13:30 0.50 DRILL P INT1 Orient MWD 13:30 - 14:00 0.50 DRILL P INT1 Make up BHA 14:00 - 14:30 0.50 DRILL P INT1 RIH with HWDP 14:30 - 15:30 1.00 DRILL P INT1 Shallow hole test MWD 15:30 - 16:00 0.50 DRILL P INT1 PJSM for Drifting DP while RIH from Derrick 16:00 - 17:00 1.00 DRILL P INT1 Drift stuck in frost in Tool joint. Start to lay down stand and drift dropped to bottom of stand. Decided to cancel plan to drift Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 5 of 23 Operations Summa Report Legal Well Name: N831 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/1/2001 16:00 - 17:00 1.00 DRILL P INT1 DP. 17:00 - 21:00 4.00 DRILL P INT1 Tag ES cementer at 1605. Test casing to 1000 PSI. Drill ES cementer. Test Casing to 1000 PSI for 5 minutes. Blow down lines. 21:00-23:00 2.00 DRILL P INT1 RIHto2900. Washto Baffle Adaptor at 3150. 23:00 - 00:00 1.00 DRILL P 'INT1 Test casing to 2500 PSI for 30 minutes 5/2/2001 00:00 - 00:30 0.50 DRILL P INT1 PJSM -- Test 13-3/8" Casing. Note: Discussed the importance of well control and reviewed the D1, D2 and D5 drills with the rig crew. 00:30 - 03:00 2.50 DRILL P INT1 Drill out Float Track, Rathole, and 20' of new fm to 3269' md. Notes: 1. Cement on top of LC and between FC and LC drilled at 60 fph with 20K WOB. 2. No sign of hard cement below the FS and in rathole -- didn't take weight just washed down. 03:00 - 03:30 0.50 DRILL P INT1 Circulate for LOT until MWin = MWout. 03:30 - 04:00 0.50 DRILL P INT1 Perform LOT -- 15.3 ppg EMW. Note: Drlg Rep and Motorman conducted LOT while Driller, Drill Crew, Mud Engineer and Baroid attended PJSM for the displacement out of critical path during LOT. 04:00 - 05:00 1.00 DRILL P INT1 Displace well with new KCL/Polymer drilling fluid. Note: Proactive LL (PLL) suggested in PJSM. Empty the L Pit into the G&I thru the Mud Header Line instead of the trough. This was successful and allowed the displacement rate to be increased from 8 bpm max (due to bottle neck in G&I with overflowing the auger trough) to 16 bpm while also el!minating spill potential. 05:00 - 06:00 1.00 DRILL P . INT1 Shut down to clean the old mud out of the L Pit and the lA suction pit prior to adding new drilling fluid. Note: PLL -- These pits were cleaned earlier while running surface casing to ensure the majority of the time required was spent out of critical path -- the hour needed here was simply a sea water flush with the gun lines and a final rinse. 06:00 - 12:00 6.00 DRILL P INT1 Drlg f/3269' to 3695' md. Note: Bit balled up at start of drilling, pumped 20 ppb medium walnut hull pill and cleaned up immediately. 12:00 - 00:00 12.00 DRILL P INT1 Drlg f/3695' to 4785' md. Note: Reactive Lesson Learned) RLL -- Experienced problem with MWD survey signal able to extend survey interval due to Iow inclination so skip survey at the stand and drilled ahead while investigating problem. When on bottom drlg, we recieved signal; however, when pickup to survey at connection lost signal. Press on and off bottom was 1450 and 1250 psi, respectively. Checked pressure on pulsation dampeners -- 1000 psi. DD suggested that we needed more differential between the on pump pressure and the pulsation dampener in order to get an MWD signal. Reduced the pulsation dampener pressure to 750 psi and recieved signal with pumps off bottom -- took MWD survey. Also realized that one pulsation dampener in not operating -- run both mud pumps on one pulsation dampener and line up equipment and tools to repair during scheduled short trip @ 5350' md. 5/3/2001 00:00 - 06:30 6.50 DRILL P INT1 Drlg f/4785' to 5350' md -- no problems. Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 6 of 23 Operations Summa Report Legal Well Name: N831 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/3/2001 06:30 - 08:00 1.50 DRILL P INT1 Circ fiber sweep around, shut down pumps, monitor well -- static, pump dry job and blow down top drive and lines. 08:00 - 10:00 2.00 DRILL P INT1 POOH 13 stands to 4691' -- swabbing on stand 13. Notes: 1) Stands 1-6 pulled with 5-25K drag. Stands 7-9 pulled with 5-40K drag. Stands 10-12 pulled with 5-60k drag and stand 13 swabbed. 10:00 - 11:30 1.50 DRILL P INT1 Backreamed stands 14 - 23 to 13-3/8" surface shoe. Notes: 1) Straght pull attempted on std 27 (~2812' 2900' md -- swabbed) 2) Tracked BHA schematic along mud log print out and seen no real distinction between overpulls associated with sands or clays -- tight spots are eratic and continuous thru upper 'interval. .3) Inidcaiton of increased torque and 250 psi pressure . differential (inc from 550 psi to 800 psi) when backreamed bit into shoe which could be interpreted as clay ball around bit and motor. -- seen 100 psi pump differential when stabilizers backreamed into shoe (less bailing around string stabilizers). 11:30 - 12:30 1.00 DRILL P INT1 Blow down top drive, mud line and clean rig floor. PJSM for Slip and Cut Drill Line. 12:30 - 13:00 0.50 DRILL P INT1 Safety Time Out (Circ over top of hole while lined up on trip tank) -- Discussed the proper use of tools, gloves, and the ,responsibility of each individual to be accountable for their own ' safety first and then the safety of those working around them. 13:00 - 15:30 2.50 DRILL P INT1 !PJSM -- Slip and Cut Drill Line (102'). 15:30 - 16:00 0.50 DRILL P INT1 ;Adjust Brakes. 16:00 - 17:00 1.00 DRILL P INT1 :Service Top Drive and Crown. 17:00 - 18:00 1.00 DRILL P INT1 ~Wiper Trip back in hole to 5350' md -- no problems. 18:00 - 00:00 6.00 DRILL P INT1 .Drlg f/5350' to 5732' md. Note: Clays are drilling slow and sands are drilling fast as expected. Adjusting drilling parameters to optimize drilling of each. 5/4/2001 00:00 - 12:00 12.00 DRILL P INT1 Drlg f/5732' to 6413' md -- no problems. 12:00 - 23:30 11.50 DRILL P INT1 Drlg f/6413' to 6959' md -- no problems. Note: Drilled to top of the Coville. Treated mud with Drill-n-slide and Condet and pretreated with 2% Torq Trim in preparation for PDC bit run and anti-bit bailing. 23:30 - 00:00 0.50 DRILL P INT1 Pump Sweep and Circ & Cond Mud while sweeping hole. 5/5/2001 00:00 - 01:30 1.50 DRILL P INT1 Circ & Cond Mud for bit trip. Note: Adding Torq Trim 2 in preparation for sliding with PDC bit run. 01:30 - 02:00 0.50 DRILL P INT1 Monitor Well -- Static. POOH 2 stands to 6780' md. 02:00 - 05:00 3.00 DRILL P INT1 Work tight hole f/6780' to 5543' md -- Swabbing on last stand. 05:00 - 08:00 3.00 DRILL P INT1 Backream f/5543' to 3650' md @ 750 gpm (1350 psi) and 60 rpm. Note: Attempted to pump out of hole -- overpull requires backreaming. 08:00 - 09:00 1.00 DRILL P INT1 POOH f/3650' to 3188' (into 13-3/8" csg shoe). Monitor well, pump dry job and blow down lines. Note: No excessive overpull, pumps or backreaming required. 09:00 - 10:30 1.50 DRILL P INT1 POOH to BHA. Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 7 of 23 Operations Summa Report Legal Well Name: N831 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/5/2001 10:30 - 14:30 4.00 DRILL P INT1 PJSM and LD BHA. Notes: 1) PJSM x 2 due to tour change. 2) BHA was clean -- no clay whatsoever on stabilizers, motor or bit. 3) Bit well worn (IADC Dull Grade 6-5-WT-A-E-1/16-ER-ROP). 14:30 - 15:30 1.00 DRILL P INT1 PJSM -- RU BOP Test Tools, Pull Wear Ring and Run Test Plug. 15:30 - 20:00 4.50 DRILL P INT1 Test BOPE 250 psi Iow & 5000 psi high. 1) AOGCC Rep Jeff Jones onsite to witness test. 2) Accumulator Test @ 3000 psi in 3:01 mini 250 psi in 0:30. 20:00 - 20:30 0.50 DRILL P INT1 RD BOPE Test Tools, pull Test Plug and Run Wear Ring. 20:30 - 21:30 1.00 DRILL P INT1 Service Top Drive, Traveling Blocks and Crown. 21:30 - 22:00 0.50 DRILL P INT1 Finished Cleaning & Inspecting Cellar. Notes: 1) During BOPE Test, bubbles were observed in cellar. Checked with Gas Detector -- not H2S and not explosive. Registered as air with 20.7% oxygen. 2) Bubbles were not present when test began when opening the annulus valve and lasted ~20 minutes once observed during the test and then quit. 3) Discussed with AOGCC Inspector -- agreed to complete BOPE test -- one test left on blind rams, then pump cellar out, clean it and check it out while service rig (See Remarks). 22:00 - 00:00 2.00 DRILL P INT1 PJSM -- MU BHA. 5/6/2001 00:00 - 01:00 1.00 DRILL N DPRB INT1 Unable to RIH with Bit and Motor past the Wear Bushing. Notes: 1) Rotated bit and motor to different orientations and attempted to run past wear bushing -- no success. 2) Pulled out of hole with bit. Backed out LD screws and retrieved wear ring -- no sign of damage or collapse to out of round. 3) Pick wear ring up with sling and slip over the bit and motor with motor hanging in blocks -- successful. 4) Decision made to leave wear ring out while Breaking out PDC from motor, MU MWD to motor lower into rotary and orient, POOH and MU PDC, RIH and set MWD in slips, slip wear ring over stump, MU DCs, pull slips and drop wear ring into place -- run in Iockdowns. RLL -- Do not attempt to run 12-1/4" PDC on 1.5 degree bh mud motor thru the wear ring. Since we generally kick off in the surface hole this may not be a frequent operation. 01:00 - 03:00 2.00 DRILL N INT1 PJSM on rig floor -- MU BHA and dropped wear ring into place as discribed above. Verify wear ring fully seated by checking paint stick mark through backed out Iockdown port -- run in four Iockdown screws in N - E - W - S orientation. 03:00 - 04:00 1.00 DRILL P INT1 Time required to make up the remaining BHA components, stab, drill collars, etc. 04:00 - 04:30 0.50 DRILL N DPRB INT1 Unsuccessful attempt to perform surface test for MWD -- Blow down top drive and mud lines. Note: Postponed test until bit and motor can be spaced outside of surface casing due to violent reactive torque and Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 8 of 23 Operations Summa Report Legal Well Name: N831 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/6/2001 04:00 - 04:30 0.50 DRILL iN DPRB INT1 backlashing while bringing pumps on -- did not exceed 30 spm before shutting down to prevent damage to both the casing and the bit. RLL: Do not attempt to pump thru 1.5 bh GT mud motor with PDC bit in 13-3/8" casing. Retrieved metal from magnets that indicate this drilling combo was producing metal shavings. 04:30 - 05:30 1.00 DRILL P INT1 PJSM -- PU ADN Tool (Clear Floor and Load Source). 05:30 - 07:00 1.50 DRILL P INT1 RIH to 3295' to position bit and motor outside the surface casing shoe. 07:00 - 07:30 0.50 DRILL 3 INT1 Shallow Test MWD @ 740 gpm & 1300 psi and established ECD baseline while rotating 50 rpm. Blowdown top drive and mud lines. 07:30 - 09:00 1.50 DRILL P INT1 RIH 3295' to 6887' md -- no problems. 09:00 - 09:30 0.50 DRILL P INT1 Precautionary ream f/6887' to 6955' @ 50 rpm and 800 gpm @ 1900 psi. Pumped 20 bbl walnut hull sweep and circulated with bit just @ bottom -- precautionary anti-bit bailing measure. 09:30 - 12:00 2.50 DRILL 3 INT1 Drlg f/6959' to 7072' md -- MWD signal failed, finished drilling down stand. Note: Bit did not show any sign of bailing; however, when differential on motor is increased above 350 psi, the bit bounces corresponding flucuations in pump pressure. 12:00 - 14:00 2.00 DRILL N DFAL INT1 Circulate a sweep. Pull 2 stands with no problems and pump a dry job in preparation to trip for failed MWD. Note: Core Rig Team rethought tripping versus drilling ahead options and determined it best to stay the course and rotate ahead toward kickoff point @ 7500' md. The following reasoning contributed to this decision: 1) The MWD tool may have debris in the modulator and could possibly unplug while drilling ahead --wishful thinking! 2) The state regulations only require a directional survey every 500' in vertical wells -- last survey was at 6882' md (0.4 degrees) and the next survey is not required until 7382' md. 3) Kickoff is not designed until 7500' md and plan calls for vertical until that point. 4) This will give the rig team a chance to evaluate the ~erformance of the DS97 bit on the GT mud motor prior to the trip in case it need to be swapped out. 4) The day tower has a new driller and 50% of the crew have been bumped up into new positions -- if we trip now, they will 'handle the BHA turn around. If we drill ahead to -,,7380' md, then chances are good the morning tower crew will catch the BHA turnaround thereby resulting in a more efficient turnaround I-- technical limit data bears this fact out, that crews who have been together for any length of time perfrom tasks in 1/3 to 1/2 the time as crews with new drillers. This is mainly attributed to training and getting used to working with and around each other -- more time required in the PJSM, etc. Secondly, the morning tower crew just handled this BHA on the trip into the hole and are familar with the technique required to drop the wear bushing into place around the BHA. 14:00 - 19:30 5.50 DRILL P INT1 Drlg f/7072' to 7358' md -- bit bouncing resulted (drill string harmonics) with increased pressure differential across the mud Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page9 of 23 Operations Summary Report Legal Well Name: NS31 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/6/2001 14:00 - 19:30 5.50 DRILL 3 INT1 motor (WOB). Notes: 1) Attempted to vary the drilling parameters to optimize the drill rate while eliminating the tendenacy for the bit to bounce. 2) With 800 gpm flowrate, the rotary was varied from 20 rpm to 120 rpm with no noticeable change in either drilling rate or reduction of bouncing. 3) Adjusted pump rates and WOB to achieve these results: Pump Off Bottom Diff@ which ROP Rate Press Bouncing Occurs (GPM) (PSI) (PSI) (FPH) 800 1550 1900 (350) 60-90 700 1300 1500 (200) 40-50 600* 1175 1300 (125) 20-30 * Note: This 600 gpm flowrate in this GT mud motor results in the same rpm that the XP mud motor run in NS27 had. Conclusion of bit bouncing: This is vertical hole and in the early days in Prudhoe shock subs were run to eliminate this reaction which was evident on every vertical hole. These days, we drill directionally and the BHA lays against the side of the hole and is stabilized and this drill string dynamic is eliminated. If we were going to drill additional vertical holes or if we witnessed this condition in our near vertical wells, we should consider an accelerator or bumper sub to correct for this. 7500 is the kick off point and we expect the bouncing to go away with the angle in the hole. 19:30 - 21:30 2.00 DRILL N DFAL INT1 Pump sweep and CBU. Checked shakers -- Clean. Sweep didn't bring back anything additional. 21:30 - 22:00 0.50 DRILL N !DFAL INT1 Shut off pumps and monitor well -- Static. Pulled 5 stands with no problems and no drag. Pump dry job, blow down top drive and mud lines. Note: Got mud into air lines during blowdown -- revised procedure to prevent this in the future. 22:00 - 00:00 2.00 DRILL N DFAL INT1 POOH f/7358' to 2700' md. No problems -- hole in great shape. 5/7/2001 00:00 - 01:00 1.00 DRILL N DFAL INT1 Finish POOH to BHA @ ADN Tool. 01:00 - 02:00 1.00 DRILL N DFAL INT1 PJSM -- Clear Floor while Anadrill unloads source out of the ADN Tool. 02:00 - 03:00 1.00 DRILL N DFAL INT1 POOH with BHA f/280' to 100' -- Download Isonic @ rig floor. (Rig crew held PJSM for next operation.) 03:00 - 04:30 1.50 DRILL N DFAL INT1 Change out MWD Tool, orient with mud motor, PU and inspect Bit -- OK. Note: Bit had 4 of 6 cutters on the gauge row chipped -- most likely from shallow hole attempt inside casing. RLL -- Do not shallow test or pump with a 12-1/4" PDC bit on a 1.5 degree bh mud motor when inside 13-3/8" casing -- instead, position the bit and motor outside the casing shoe prior to pumping for any reason. DD made good call to cancel ~the shallow hole test with just 30 spm pump based on the reactive torque seen at the surface. Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 10 of 23 Operations Summa Report Legal Well Name: N831 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/7/2001 04:30 - 05:00 0.50 DRILL N DFAL INT1 PullWear Ring. 05:00 - 06:30 1.50 DRILL N DFAL INT1 RIH while MU BHA. Note: ~ 1) Download data from CDR tool on the rig floor. !2) Install Wear Ring -- Drop into place from rig floor. 13) Load ADN source -- Clear Rig Floor and Cellar of personnel ,-- Held PJSM for running in hole with drill pipe. 06:30 - 08:00 1.50 DRILL N DFAL INT1 RIH f/300' to 3295' md. Notes: Position bit and motor outside shoe-- perform shallow hole test and establish ECD baseline. 2) CDR tool is not communicating with the MWD tool -- data will still be recorded; however, there will not be real time data while drilling (PWD and GR/RES are affected -- the MWD has GR). Decision made to drill ahead without realtime data. 08:00 - 08:30 0.50 DRILL N DFAL INT1 Perform shallow hole test and establish ECD baseline @ 800 gpm and 50 rpm. Note: CDR tool is not communicating with the MWD tool -- data will still be recorded; however, there will not be real time data while drilling (PWD and GR/RES are affected -- the MWD has GR). Decision made to drill ahead without realtime data. ;08:30 - 10:00 1.50 DRILL N DFAL INT1 RIH f/3295' to 7100' md - hole in good shape. 10:00 - 11:00 1.00 DRILL N DFAL INT1 Fill drill pipe, shoot survey @ 7171' md -- precautionary ream to 7358' while pumping 20 ppb wallnut hull pill for anti bit bailing. 11:00 - 12:00 1.00 DRILL P INT1 Slide Drlg f/7358' to 7374' to begin kick off. Note: CDR tool began communicating with MWD. 12:00 - 00:00 12.00 DRILL P ;INT1 Drlg f/7374' - 7830' md while kicking well off. Note: CDR tool intermittently communicates with MWD. 5/8/2001 00:00 - 12:00 12.00 DRILL P INT1 Drlg f/7830' to 8231' md. Notes: 1) Seepage losses of ~ 6 ot 8 bph over 6 to 8 hours. Strung 2 pallets of barafibre and healed losses. 2) Continue building in planned kickoff ART 4.2 hrs/AST 5.7 hrs. Sliding ~30'/stand. 3) Bit bouncing (Drill String Harmonics?) still occuring when differential pressure > 250 psi is applied to the motor. 12:00 - 00:00 12.00 DRILL P INT1 Drlg f/8231' to 8570' md. Notes: 1) Continue building in planned kickoffART 4.6 hrs/AST 6.8 hrs. Increased sliding to ,,,45' per stand. 2) Shut off centrifuges @ 8450' md and began planned weight up as per program. 3) Bit bouncing (Drill String Harmonics?) still occuring when differential pressure > 250 psi is applied to the motor. Expecting this to change once top stabilizer is through the build section or again with upcoming formation change. Have tandem thruster lined up for contingency. 4) Attempted to apply more differential on motor at 8500' md. Bit began bouncing @ 250 psi differential -- steadily increased differential to 500 psi with no positive effect. Returned to drilling with 250 psi differential. 5/9/2001 00:00 - 14:00 14.00 DRILL P INT1 Drill and slide from 8570' to 9116'. Drill string continued to Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 11 of 23 Operations Summa Report Legal Well Name: N831 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/9/2001 00:00 - 14:00 14.00 DRILL !P INT1 bounce with varied WOB, Rotary RPM and Pump Rates. Gas started increasing at 9116'. P/U off bottom. 14:00 - 16:30 2.50 DRILL P INT1 Circulate out gas. Bit depth 9116' MD 9037' TVD. Max gas 8704 units. Mud cut 9.8 to 8.7 ppg. 16:30 - 17:00 0.50 DRILL N RREP INT1 Continue to circulate with #2 mud pump while repairing leak in #1 mud pump pulsation dampner X-O swedge. 17:00 - 18:00 1.00 DRILL P INT1 Drill from 9116' to 9158' with pump rates at 95 spm and 120 spm. Drill string bouncing stopped. ROP 30 - 60 fph. Able to maintain 400-500 psi motor differential. Gas started increasing. 18:00-18:30 0.50 DRILL P INT1 ' Circu ate out gas. Bit depth 9158' MD 9047'TVD. Maxgas 6573 units. Mud cut 9.8 to 8.8 ppg. 18:30 - 00:00 5.50 DRILL P INT1 Drill and slide from 9158' to 9330'. No drill string bounce. Pump rates 95 spm and 120 spm. Maintain 400-500 psi motor differential. ROP 30-60 fph. 5/10/2001 00:00 - 02:30 2.50 DRILL P INT1 Drill / slide from 9330' to 9438'. No drill string bounce. Running 95 spin and 120 spm on mud pumps. Maintain 400-500 psi motor differential. ROP -50 fph. 02:30 - 04:30 2.00 DRILL P INT1 Circulate bottoms up. Spot 70 bbls Steel Seal pill across the Schrader Bluff formation. 04:30 - 07:30 3.00 DRILL P INT1 Wiper trip from 9438' to 7265'. Hole slick. No problems. 07:30 - 13:30 6.00 DRILL P INT1 Rotate and reciprocate pipe while weighting up mud system from 9.8 to 11.3 ppg for Kingak drilling. 13:30 - 23:00 9.50 DRILL P INT1 Drill / slide from 9438' to 9911'. No drill string bounce. Running 95 spm and 120 spm on mud pumps. Maintain 400-500 psi motor differential. ROP -,40-80 fph. 23:00 - 00:00 1.00 DRILL N RREP INT1 Change swab in #2 mud pump. 5/11/2001 00:00 - 08:00 8.00 DRILL P INT1 Drill from 9911' to 10372'. No drill string bounce. 08:00 - 08:30 0.50 DRILL N RREP INT1 Change out swab in #1 mud pump. 08:30 - 09:30 1.00 DRILL P INT1 Drill from 10372' to 10406'. :09:30 - 18:00 8.50 DRILL N RREP INT1 Change out swab in #2 mud pump. This was the same liner that a swab had been changed out at 2300 hrs the previous night. Decision made to change out all swabs and liners in both mud pumps. Mud pump #1 had ~690 hrs on the liners, and mud pump #2 had ~650 hrs on the liners. All the liners were showing definite wear. Continue to circulate with 1 pump at a time and rack back a stand every 30 minutes. 18:00 - 18:30 0.50 DRILL N RREP INT1 GIH back to bottom to start drilling after mud pump repairs. 18:30 - 19:30 1.00 DRILL P INT1 Drill from 10406' to 10448'. 19:30 - 20:30 1.00 DRILL N RREP INT1 Flange on the #1 mud pump high pressure discharge line started leaking. Tighten flange bolts. Stop leak. 20:30 - 00:00 3.50 DRILL P INT1 Drill from 10448' to 10636'. At 10612' ROP went from ~75 fph to 16 fph. P/U off bottom and pump 2 - 20 bbls / 15 lbs / bbl nut plug sweeps. Vary WOB, Rotary, and SPM. ROP consistent at 15-20 fph. No change in formation samples. Discuss with Geologist. Continue to drill ahead to get Gama Ray across the 10612' section. 5/12/2001 00:00 - 09:00 9.00 DRILL P INT1 Drill ahead to 10636'. No drill string bounce. ROP still ,,-20 fph. Pump 3rd 20 bbls 15 lb / bbl nut plug sweep. No change in ROP. Continue to drill ahead. 09:00 - 09:30 0.50 DRILL N RREP INT1 Re-charge #2 mud pump pulsation dampner to 650 psi. 09:30 - 18:30 9.00 DRILL P INT1 Drill ahead to final hole section TD. Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 12 of 23 Operations Summary Report Legal Well Name: NS31 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/12/2001 09:30 - 18:30 9.00 DRILL P INT1 Geology picked top of Sag River at 10867' MD 10715' TVD. ROP increase 20 to 37 fph. Max gas 1208 units. Geology picked final hole TD at 10945' MD 10791' TVD. 18:30 - 20:30 2.00 DRILL P INT1 Circulate bottoms up for samples and wiper trip. Bottoms up sample showed silty sandstone indicating Sag River formation. 20:30 - 23:00 2.50 DRILL P INT1 Wiper trip 24 stds up through the top of the HRZ. Max pull through the Kingak was 25k over. Rest of the trip was slick. No problems. 23:00 - 00:00 1.00 DRILL P INT1 GIH to TD. Hole slick. No problems. 5/13/2001 00:00 - 02:30 2.50 DRILL P INT1 Circulate out after wiper trip at TD, and condition mud for running casing. Trip gas 164 units. 02:30 - 04:00 1.50 DRILL P INT1 Spot 75 bbls Steel Seal LCM pill across the Schrader Bluff formation, and pump down Sperry Sun 1.8" gyro. 04:00 - 09:00 5.00 DRILL P INT1 Pump slug. Blow down top drive. POOH to 13 3~8" casing shoe. Hole slick. No problems. 09:00 - 10:30 1.50 DRILL P INT1 Slip / cut drill line. 10:30 - 11:30 1.00 DRILL P INT1 Service top drive, blocks, and crown. 11:30 - 13:00 1.50 DRILL P INT1 POOH to last stand of drill pipe. 13:00 - 15:00 2.00 DRILL P INT1 Change top rams from drill pipe VBR's to 9 5/8" casing rams. 15:00 - 20:30 5.50 DRILL P INT1 POOH to ADN. Unload source. Continue POOH to BHA and LID same. No bailing on stablizers. Bit balled up. Three junk slots and corresponding nozzles plugged up. Significant wear on bit cutters. 20:30 - 22:00 1.50 DRILL P INT1 Pull wear bushing. Set test plug and test 9 5/8" casing ram doors to 1000 psi. 22:00 - 00:00 2.00 DRILL P INT1 R/U 9 5/8" casing tools. 5/14/2001 00:00 - 01:00 1.00 DRILL P INT1 Finish R/U casing tools and hold PJSM for running casing. 01:00 - 03:30 2.50 DRILL P INT1 Bakerlok bottom three joints of casing. Break circulation to ensure floats are open. Continue running 9 5/8", 53.50#, L-80, BTCM casing. 03:30 - 05:30 2.00 DRILL N RREP INT1 Part electrical wiring for stabbing board while moving the stabb ng board down. Replace electrical wiring and secure ,same. 05:30 - 08:00 2.50 DRILL P INT1 Continue running a total of 75 jts 9 5/8" casing to 3100' (13 3/8" shoe at 3237'). 08:00 - 09:00 1.00 DRILL P INT1 Circulate bottoms at the 13 3/8" shoe. Maintain full returns. 09:00 - 20:30 11.50 DRILL P INT1 Continue running 9 58" casing. Run a total of 266 jts. Hole slick until last 5 ft of joint #266. Start taking weight. Normal P/U off slips 425k. Normal S/O 325k. 20:30 - 21:30 1.00 DRILL P INT1 M/U casing hanger and pup joint. P/U landing joint and M/U same. Fill casing using the Franks fill-up tool. Pump a total of 89 bbls at 2-4 bpm with no returns while attempting to move casing. P/U casing off slips. Casing stuck up / down. Max P/U to 675k. Max S/O to 150k. With 89 bbls pumped pump 3ressure went to 2200 psi and jugged. 21:30 - 23:00 1.50 DRILL N DPRB INT1 RID Franks fill-up tool to allow for higher circulating pressure. Blow down top drive. M/U Halliburton cement head. :23:00 - 00:00 1.00 DRILL N DPRB INT1 Stage pump rate up to 3200 psi at 500 psi increments and surging back attempting to clear blockage. Broke down at 3200 psi. Continue to attempt to get circulation while working casing. Able to slowly work casing down and land casing Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 13 of 23 Operations Summary Report Legal Well Name: NS31 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/14/2001 23:00 - 00:00 1.00 DRILL N DPRB INT1 hanger while pumping fluid away with no returns. Max P/U 700k until hanger entered BOPS. Casing hanger would hang up on the rams. Note: This summay goes through 0200 hrs Tuesday. 5/15/2001 00:00 - 01:00 1.00 CASE P INT1 Continue to attempt to get circulation while working casing. Able to pump fluid away with no returns. Continue to gain casing string weight while pumping fluid away. Continue to work casing down. Eventually land casing hanger with 80k down. Still able to pump fluid away at any pump rate with no returns. 01:00 - 04:30 3.50 CASE P INT1 PJSM - L/D Franks casing fill-up tool and 350 ton casing elevators. Clean and prepare rig floor to R/U Schlumberger wireline. 04:30 - 08:30 4.00 CASE N DPRB INT1 PJSM - Spot Schlumberger wirleine unit and R/U wireline sheaves. Prepare wireline cable head. Bring USIT to rig floor and calibrate same. 08:30 - 10:30 2.00 CASE N DPRB INT1 GIH with Schlumberger USlT. 10:30 - 17:00 6.50 CASE N DPRB INT1 Log USlT on depth. Log out from 10820' to 6000'. Continue to POOH and LID USIT. 17:00 - 20:30 3.50 CASE N DPRB INT1 Prepare 1-5 ft 4 1/2" perf gun with 12 spf at 45 degree phase. Hold PJSM with all rig personnel. Bring pef gun to rig floor and verify length between CCL and top shot. Arm perf gun. 20:30 - 21:30 1.00 CASE N DPRB INT1 Perf gun depth at ~7800'. PLQ lost generator power which shut down the wireline unit. Note: The Schlumberger wireline unit gets power from the pipe rack with is powered by the PLQ. 21:30 - 23:30 2.00 CASE N MISC INT1 Operations trouble shoot PLQ generator problem. Unable to repair generator. PJSM - Drilling rig fired up all 5 generators and back feed power to the PLQ. Note: The PLQ supplies power to the pipe rack, G&I, and Halliburton. 23:30 - 00:00 0.50 CASE N MISC INT1 Monitor back feed power supply between the rig and the PLQ before continue GIH with perf gun. 5/16/2001 00:00 - 00:30 0.50 CASE N MISC INT1 Continue to monitor back feed power between the drilling rig and the PLQ before continue GIH with perf gun. Power appears to be smooth and OK. 00:30 - 03:00 2.50 CASE N DPRB INT1 Log perf gun on depth. Perforate 10811'- 10816'. This put the top shot 10' below the first casing collar above the float collar. Monitor well for losses. No losses. POOH with perf gun and L/D same. All shots fired. R/D wireline sheaves. 03:00 - 04:30 1.50 CASE N DPRB INT1 R/U 350 ton casing elevators. R/U Haliburton cementing head and cementing hose. 04:30 - 13:00 8.50 CEMT P INT1 Break cirulation at 1 bpm at ~1000 psi and maintain returns. Slowly stage pump rate up to 12 bpm and mantain full returns. Max gas 1200 units. Balance out the mud in the hole with fluids in the pits to 11.0 ppg. No significant increase in cuttings across the shakers. Kingak shale appears to be stable with no running. Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 14 of 23 Operations Summary Report Legal Well Name: NS31 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From-To Hours Activity Code NPT Phase Description of Operations 5/16/2001 04:30 - 13:00 8.50 CEMT P INT1 Discuss and receive revise cementing procedure while circulating. Perform load test on rig generators. Put one rig mud pump on line along with additional loads from the PLQ, Halliburton and G&I. Load before with just the rig and PLQ = 1.3 meg. Load after adding Halliburton and G&I = 1.7 meg. Total available load = ,,-3.0 meg. PJSM for cementing while circulationg. 13:00 - 17:30 4.50 CEMT P INT1 Mix and pump the following: Lead - Premium G Econolite, 530 sks, 306.3 bbls, Wt 11.2, Yield 3.24, GPS 20.4. Bottom plug Tail - Premium G, 977 sks, 200 bbls, Wt 15.9, Yield 1.15, GPS 5.0. Top wiper plug 25 bbls seawater Rig displace with mud 729 bbls. Follow prescribed pumping schedule. Cut displacement to perfs short by 10 bbls (Leaves .~140 cement in casing). Final pump pressure at 5 bpm = 1100 psi. Shut in pressure = 800 psi. Note: While displacing with rig at 12 bpm (70 spm each pump) found a volume pumped difference of ~17 bbls between the rig total strokes pumped and the Halliburton flow meter. Go to just one mud pump and compare mutiple strokes pumped vs Halliburton flowmeter. Both were tracking each other. Discuss with the Office and decide to use the Halliburton flow meter volume for final displacement volume. 17:30 - 21:00 3.50 CEMT P INT1 WOC - Displace 13 3/8"x 9 5/8" annulus with one annulus volume. Pump at 1/2 bpm. Broke down at 880 psi to 435 psi. Continue displacing annulus at 1 bpm. Total pumped 193.4 bbls. Final pump pressure ~550 psi. 21:00 - 00:00 3.00 CEMT P INT1 WOC - Load and strap drill pipe in pipe shed. Cleaning pits. Clean cellar area. Disconnect turn buckets on BOPS. Pull mouse hole and L/D in pipe shed. Latch onto BOPS with bridge crane. 5/17/2001 00:00 - 01:30 1.50 CEMT C INT1 Finish WOC 8 hrs. Continue to load and strap drill pipe in pipe shed. Cleaning mud pits. 01:30 - 02:30 1.00 CEMT C INT1 Bleed off casing pressure. Pressure built to 2200 psi. L/D cementing head. Clean rig floor area. 02:30 - 04:30 2.00 WHSUR C INT1 Split and P/U BOPS. 04:30 - 05:30 1.00 WHSUR C INT1 P/U to 605k at the weight indicator / 540k at the emergency casing slips to clear the casing collar. Put 2 come-on-alongs around the casing to center the casing up in the wellhead to be Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 15 of 23 Operations Summa Report Legal Well Name: N831 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/17/2001 04:30 - 05:30 1.00 WHSUR C INT1 able to drop the slips. 05:30 - 07:00 1.50 WHSUR C INT1 Make rough cut on casing and L/D hanger. 07:00 - 08:30 1.50 WHSUR C INT1 N/D bell nipple and move BOPS out from over the wellhead. 08:30 - 10:00 1.50 WHSUR C INT1 N/U Vetco Gray casing cutter and make final cut on casing. 10:00 - 10:30 0.50 WHSUR C INT1 Set seal assembly. 10:30 - 13:00 2.50 BOPSUF C INT1 N/U BOPS. Test seal assembly to 5280 psi (80% of casing collaspe) for 15 minutes. Test OK. 13:00 - 14:30 1.50 BOPSUF.C INT1 Change 9 5/8" rams to 2 7/8" x 5 1/2" VBR's. 14:30 - 18:30 4.00 BOPSUF C INT1 N/U bell nipple. Set wear bushing. 18:30 - 19:30 1.00 BOPSUF.P INT1 Pressure test 9 5/8" casing to 3000 psi for minutes and chart. Took 7.8 bbls. Test OK. Bled off ~200 psi on chart recorder and 10 psi on the digital gauge. 19:30 - 21:00 1.50 DRILL P INT1 L/D casing elevators. Change from long bails to short bails. P/U drill pipe elevators. R/U misc rig floor equipment. 21:00 - 00:00 3.00 DRILL C INT1 Swap out drill pipe - P/U mule shoe and GIH open ended with drill pipe out of derrick. 5/18/2001 00:00 - 03:00 3.00 DRILL C INT1 Finish GIH to ~10,000' with 5" drill pipe out of derrick. 03:00 - 08:00 5.00 DRILL C INT1 POOH and LID 40 stds drill pipe. Test choke manifold while POOH. 08:00 - 10:00 2.00 DRILL C INT1 Finish GIH with the remaining 40 stds of the 5" drill pipe out of the derrick. 10:00 - 17:30 7.50 DRILL C INT1 POOH and LID remaining 5" drill pipe. 17:30 - 20:00 2.50 DRILL P INT1 R/U to freeze protect the 13 3/8" x 9 5/8" annulus. Drain BOPS, pull wear bushing, set test plug, and P/U test joint. PLQ power went down. Need PLQ power to transfer diesel ,through the pipe rack to the rig. 20:00 - 21:30 1.50 DRILL P INT1 ' PJSM for pumping freeze protect and testing BOPS. PLQ continue to experience problems with PLQ generator. Have the stand-by generator package carry the PLQ only, and have the Rig generators carry the Rig, G&I, and Halliburton. 21:30 - 23:30 2.00 DRILL P INT1 Freeze protect 13 3/8" x 9 5/8" annulus with 108 bbls diesel, 5 bbls Escaid. Max pump pressure 1200 psi. 23:30 - 00:00 0.50 DRILL P INT1 RID lines for freeze protection. 5/19/2001 00:00 - 00:30 0.50 DRILL P INT1 R/U kill line back onto kill line side of BOPS. 00:30 - 05:30 5.00 DRILL P INT1 Test BOPS. Test Hydril to 250-3500 psi. Test all rams, BOP stack valves, floor valves, top drive valves, kelly hose, and stand pipe to 250-5000 psi. Tests OK. Pull test plug and L/D same. AOGCC John Crisp waived witness of BOP test 1430 hrs 5/18/01. 05:30 - 08:30 3.00 DRILL C INT1 P/U out of pipe shed and GIH with 84 jts 5" drill pipe. Rabbit each joint. 08:30 - 10:00 1.50 DRILL C INT1 POOH and rack back 28 stds (84 jts) of 5" drill pipe. 10:00 - 11:00 1.00 DRILL P INT1 Service top drive, blocks, and crown. 11:00 - 12:00 1.00 DRILL P INT1 Change slip dies in drill pipe air slips and Iron Roughneck. Re-number drill pipe in pipe shed. 12:00 - 14:30 2.50 DRILL P INT1 M/U 8 1/2" BHA and GIH. 14:30 - 23:30 9.00 DRILL C INT1 P/U out of pipe shed and GIH 300 jts of 5" drill pipe. 23:30 - 00:00 0.50 DRILL C INT1 Tag cement at 10486' and set 25k weight down. M/U top drive, break circulation, and start reaming down at +100 ft/hr. WOB 0-3, Rotary 60, SPM 150 (12.7 bpm), Torque 9k, Drill pipe AV 275 Tag top wiper plug at 10596'. Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 16 of 23 Operation Summa Report Legal Well Name: NS31 ICommon Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/19/2001 23:30-00:00 0.50 DRILL C INT1 WOB 10-15, Rotary60, SPM 180(15.3 bpm), Torque 10k, Drill pipe AV 328 Calculated top at cement 10671'. 5/20/2001 00:00 - 10:00 10.00 DRILL P PROD1 Tagged top wiper plug at 10596'. WOB 10-15, Rotary 60, SPM 180 (15.3 bpm), Torque 10k, Drill pipe AV 328. Continue driling cement at 60-70 fi/hr through perfs in casing at 10811'- 10816'. Did not hang up going through perfs. Continue drilling cement 60-70 ftJhr down to float collar at 10846'. Drill through float collar. No hard cement below float collar. Continue rotating down to the float shoe at 10933'. Drill through float shoe. Continue rotating down through the 12 1/4" rat hole slowly minimizing the possibility of any cement chunks falling on top of the BHA. No hard cement below the float shoe. Drill 20' of new hole with 10.3 ppg mud. Perform FIT with 10.3 ppg mud while drilling / circulating. No losses. 10:00 - 11:00 1.00 DRILL = PROD1 Circulate bottoms up. Pull back up inside the shoe. Blow down top drive. Monitoring well. No losses. 11:00 - 12:00 1.00 DRILL = PROD1 Clean the L-Pits and #1 mud pit. 12:00 - 15:00 3.00 DRILL P PROD1 Swap out drilling mud to 9.3 ppg Drill-n-Fluid. 15:00 - 17:00 2.00 DRILL P PROD1 Continue to circulate and build 70 bbls 130 Ib/bbl LCM pill. Building ',,600 bbls 9.3 ppg Dill-n-Fluid mud in the G&I. 17:00 - 00:00 7.00 DRILL P PROD1 Drill 8 1/2" hole from 10945' to 11112'. WOB 30-40k, SPM 120-180, SPP 700-800 psi, Rotary 100-120, Torque 10-15k. No losses. 5/21/2001 00:00-22:00 22.00 DRILL P PROD1 :Drill from 11112' to TD11440' MD 11280'TVD. TDpickby Geologist / Engineer. WOB 40k, SPM 150 (535 gpm), SPP 1125, Rotary 100, Torque 12-13k. No losses while drilling. Pick top of Kavik 11385' MD. 22:00 - 22:30 0.50 DRILL P PROD1 Monitor well. No gain / loss. POOH 6 stds up inside 9 5~8" shoe. Hole slick. No problems. 22:30 - 23:00 0.50 DRILL P PROD1 Monitor well. No gain / loss. GIH to TD at 11440'. Hole slick. No problems. 23:00 - 00:00 1.00 DRILL P PROD1 Circulating 1 1/2 bottoms up. Rotate and reciprocate pipe. Trip gas = 141 units BGG drilling / circulating = ,,,35 units 5/22/2001 00:00 - 00:30 0.50 DRILL P PROD1 Finish circulate / condition prior to POOH to wireline log. Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 17 of 23 Operations Summa Report Legal Well Name: N831 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/22/2001 00:30 - 01:30 1.00 DRILL P PROD1 Drop Sperry Sun gyro and pump down same. 01:30 - 02:00 0.50 DRILL P PROD1 Pump slug. POOH 6 stds inside of 9 5/8" casing shoe. Blow down top drive. 02:00 - 08:00 6.00 DRILL P PROD1 Strap POOH to BHA. 08:00 - 09:30 1.50 DRILL P PROD1 Rack back 1 std drill collars. L/D in 1 piece bit, stabilizers, and lead collar. Clean rig floor area. 09:30 - 11:00 1.50 DRILL P PROD1 R/U Schlumberger wireline. 11:00 - 20:00 9.00 DRILL P PROD1 #1 - Schlumberger wireline logging run. Quad Combo - Gama Ray / Neutron Density / Laterlog / Resistivity. Hole slick. No pulls. 20:00 - 00:00 4.00 DRILL 3 PROD1 #2 - Schlumberger wireline logging run. Gama Ray / Dipole Shear Sonic / Array Induction Resistivity. Hole slick. No pulls. 5/23/2001 00:00 - 02:00 2.00 EVAL 3 PROD1 Continue Logging Run #2 (GR/DSI/AIT) 02:00 - 03:00 1.00 EVAL 3 PROD1 Rig down Logging tools. 03:00 - 05:30 2.50 EVAL 3 PROD1 RU logging tools for Logging Run #3 (MDT) via drill pipe convey. 05:30 - 08:00 2.50 EVAL ~ PROD1 RIH with MDT Logging tools on DP 08:00 - 09:30 1.50 EVAL 3 PROD1 Move HWDP in derrick, fill drill pipe, and check emergency shutdown. 09:30 - 11:00 1.50 EVAL 3 PROD1 RIH @ 35 to 40 fpm with MDT logging tool on bottom of 5" dp. 11:00 - 12:00 1.00 EVAL 3 PROD1 Fill Pipe. Note: Circulation is limited with DPC tools (<3bpm & <1000 Jpsi). 12:00 - 17:30 5.50 EVAL P PROD1 . Continue RIH with MDT logging tool on bottom of 5" dp. 17:30 - 18:30 1.00 EVAL P PROD1 PJSM & RU wireline sheaves and MU TIW Valve and Sidedoor Entry Sub. 18:30 - 20:30 2.00 EVAL P PROD1 RIH with wireline and wet connect to latch into the drill pipe conveyed MDT tool -- latch up and test OK. 20:30 - 00:00 3.50 EVAL P PROD1 Begin logging with MDT at 10933' md. Note: Plan is to acquire 31 pressure sets and 6 sample sets. 512412001 00:00 - 00:00 24.00 EVAL P PROD1 Continue taking pressures and samples with the MDT via drill pipe convey. Notes: 1) All pressure points in the Ivashak fm. were successful. 2) All sample points in the Ivashak fm. were successful taken. 3) Unable to attain pressure readings in the Sag River fm. 4) Detail of pressure and sample points to follow on tomorrow's report. 5/25/2001 00:00 - 03:00 3.00 EVAL P PROD1 Finish gathering pressures and samples f/11327' to 11402' md. Notes: 1) Total Pressures taken were 38 and total samples taken were six 450 cc chambers, three 1 gallon chambers and one 2.75 gallon chamber -- these were all in the Ivashak formation. 2) Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 18 of 23 Operations Summa Report Legal Well Name: N831 'Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/25/2001 00:00 - 03:00 3.00 EVAL P PROD1 Attempts to get pressures in Sag River were unsuccessful. 03:00 - 03:30 0.50 EVAL P PROD1 POOH to sidedoor entry sub and hold PJSM with Schlumberger for POOH with wireline and RD Sheaves. 03:30 - 05:00 1.50 EVAL P PROD1 POOH with E-Line, LD side door entry sub and RD wireline sheaves. Note: Derrickman noticed cracks in a 6" x 6" square tubing cross member in the derrick. The cracks were at weld points where a channel iron was welded to which was attached the derrick board. 05:00 - 07:00 2.00 EVAL ~ PROD1 Slip and Cut drill line and adjust brake. Notes: 1) Tool Pusher and Rig Welder evaluated the cracked welds for the derrick board attachment -~ Notify NAD drlg supt. 2) Pictures taken to be sent to Anchorage for evaluation by rig engineer. 3) Rig engineer to consult DRECO for repair plan. 07:00 - 07:30 0.50 EV^L N PROD1 Held PJSM for repairing derrick board. 07:30 - 12:00 4.50 EVAL N PROD1 Remove and secured the front section of derrick board to the fingers and ground bolts of the back section of derrick board. Notes: 1) Safed out rig floor area beneath over head work on derrick board. 2) Test choke manifold out of critical path -- approval from AOGCC Field Inspector John Spaulding. 3) Calibrated Epoch out of critical path. 12:00 - 13:00 1.00 EVAL N PROD1 PJSM and HACL to weld derrick board attachment. 13:00 - 15:00 2.00 EV^L N PROD1 Removed and secured the back section of derrick board on fingers and prep derrick board for welding. 15:00 - 16:00 1.00 EVAL N PROD1 Welders Crew Change and hand over on location -- Going Home Day. 16:00 - 17:30 1.50 EV^L N PROD1 PJSM -- Welding on derrick board attachment in derrick. Note: Recieved recommendation from DRECO to reinforce the present channel iron attachments with 1/2" steel plate doublers as per NAD rig engineer. 17:30 - 18:30 1.00 EVAL P PROD1 Service Top Drive and Tugger Sheaves while welder broke for dinner. Note: PJSM held out of critical path. 18:30 - 21:30 3.00 EV^L :N PROD1 Continue welding on derrick board. 21:30 - 22:30 1.00 EV^L N PROD1 Reattach rear and front sections of derrick board to repaired channel iron attachments reinforced with 1/2" steel plate doublers as per the DRECO recommendation. Note: RIG REPAIR OF DERRICK BOARD IS COMPLETE! 22:30 - 23:00 0.50: EVAL P PROD1 Pump Dry Job. 23:00 - 00:00 1.00 EVAL P PROD1 POOH with MDT on end of 5" DP. Note: Held PJSM out of critical path prior to rig repair completion. 5/26/2001 00:00 - 03:00 3.00 EVAL P PROD1 Finish POOH with the MDT tool via drill pipe convey. 03:00 - 03:30 0.50 EVAL P PROD1 PJSM for handling MDT tools (with sample chambers). Notes: 1) Schlumberger personnel, rig crew and drlg rep present. 2) Create procedure and perform hazard risk mitigation. 03:30 - 05:30 2.00 EVAL P PROD1 Lay down components of MDT tool. Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 19 of 23 Operations Summary Report Legal Well Name: NS31 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/26/2001 03:30 - 05:30 2.00 EVAL P PROD1 Note: Take special precaution to bleed possible pressure trapped between components housing the sample chambers. 05:30 - 06:00 0.50 EVAL P PROD1 PJSM for rigging up wireline. 06:00 - 07:00 1.00 EVAL P PROD1 RU wireline sheaves and Surface Test USIT Logging Tool. 07:00 - 12:00 5.00 EVAL P PROD1 Perform Logging Run 4 (USlT) on wireline: Notes: 1) Log indicated >50' of cement in the first 200' above the top of Sag River formation -- Excellent Cement Bond. 2) Log indicated >50' of cement in the first 200' above the top of Kuparuk formation -- Good Cement Bond. 3) TOC for lead looks to be @ -3800' md. 4) Sent PDS file of USIT electronic file to Anchorage team via email. 5) Monitored hole while circulationg across the top of hole while lined up on the trip tank -- hole static. 12:00 - 12:30 0.50 EVAL P PROD1 RD wireline unit. 12:30 - 13:00 0.50 EVAL P PROD1 PJSM -- BOP Test. 13:00 - 13:30 0.50 EVAL P PROD1 Pull Wear Ring 13:30 - 14:00 0.50 EVAL P PROD1 Drain Stack utilizing the HVAC. 14:00 - 14:30 0.50 EVAL P PROD1 Install Test Plug and fill with sea water. 14:30 - 18:30 4.00 EVAL P PROD1 Test BOPE as per BP Policy. Notes: 1) 250 psi Iow for 5 min & 5000 psi high for 10 min. 2) AOGCC Field Inspector John Spaulding waived witnessing , the test. 18:30 - 19:30 1.00 EVAL P PROD1 Pull Test Joint and Install Wear Ring. Blow down lines. :19:30 - 20:00 0.50 EVAL P PROD1 MU BHA #7 for conditioning trip. 20:00 - 00:00 4.00 EVAL 3 PROD1 RIH to 9-5/8" casing shoe. 5/27/2001 00:00 - 01:00 1.00 EVAL 3 PROD1 Fill DP & Circ @ 10918' inside 9-5/8" casing shoe. Note: 110 spm @ 675 psi (PU 305K, SO 265K & RotWt 300K) 01:00 - 01:30 0.50 EVAL ~ PROD1 RIH f/10918' - 11397' md. Notes: 1) There was no indication of drag; infact, the SO wt inc fl 285K to 290K probably due to S Shape of wellbore. 01:30 - 03:30 2.00 EVAL ~ PROD1 Wash down f/11397' to 11440'. Notes: 1) No rotation in attempt to simulate liner run. 2) No hole problems. 3) 3 feet of fill on bottom -- wash to TD 11440 and stack 40K -- no problem. 4) Engage Rotary @ 45 rpm with 5K ft. lbs. (inc to 9K as circulation rate and volume increased). 5) Record PU 300K, SO 295K & Rot Wt 3 03:30 - 04:00 0.50 EVAL P PROD1 Monitor well -- static. Pump dry job, Blow down top drive and lines. Note: Drop 2.375 rabbit with 100' wireline tail into dp stand 109. 04:00 - 08:30 4.50 EVAL P PROD1 POOH with BHA #7. 08:30 - 09:00 0.50 EVAL P PROD1 PJSM -- LD BHA. 09:00 - 10:30 1.50 EVAL P PROD1 LD BHA #7 -- very clean with no clay. Note: See remarks regarding assessment of Conditioning Trip. 10:30 - 11:00 0.50 EVAL P PROD1 Clean rig floor. 11:00 - 14:00 3.00 CASE P PROD1 PJSM -- RU chrome running and handling equipment. Note: Change to 15 foot 500 ton bales. - Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 20 of 23 Operations Summary Report Legal Well Name: NS31 'Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From-To Hours Activity Code NPT Phase Description of Operations 5/27/2001 14:00 - 17:00 3.00 CASE P PROD1 PJSM -- Run 7" chrome liner. 17:00 - 18:30 1.50 CASE i P PROD1 MU liner hanger/packer/setting tool assy. RD chrome running and handling equipment. Change to 10 foot 350 ton bales. 18:30 - 19:00 0.50 CASE P PROD1 Run in with one stand of 5" dp. Circulate 1.5 times liner volume. Record PU and SO weights for liner. 19:00 - 00:00 5.00 CASE P PROD1 Rill with on 5" dp -o fill every 10 stands. 5/28/2001 00:00 - 03:30 3.50 CASE P PROD1 RIH w/7" liner on 5" dp to 10179' md. (Just inside 9-5/8" casing shoe.) 03:30 - 04:30 1.00 CASE P PROD1 Est Circ and gradually inc rate @ 10179' -- 117 spm (10 bpm) Note: MU Baker Cement Swivel Head and stand back DS Set Back -- out of critical path. 04:30 - 05:30 1.00 CASE P PROD1 RIH with 7" liner on 5" dp f/10179' - 11421' md -- no problems. 05:30 - 06:00 0.50 CASE P PROD1 MU Baker Cement Swivel Head (Torque all connections thru with Top Drive). 06:00 - 08:30 2.50 CASE P PROD1 Est circ and gradually inc rate from 1 bpm to 7 bpm, start reciprocation -- No Problems. Increase rate f/7 to 8 bpm and stand pipe pressure inc f/700 3si to 1400 psi and continued climbing. Slowed down pumps to 2 bpm and gradually increased rate to reestablish good circulation to 7 bpm no problem. Inc rate to 8 bpm and similar results with increased pressure. Worked with it with pressure swings while reciprocating. Increased rate to 8 bpm and decision to circuate liner with out reciprocation since unable to determine if tool hydraulicing at higher rate or if increased rate is eroding hole and cutting are trying to packoff in annulus space between flex lock hanger and 9-5~8" casing. Note: Csg ID 8.535" and Flex Lock OD is 8.3". 08:30 - 09:30 1.00 CASE ~ PROD1 Pump 10 bbls sea water and test lines to 4500 psi--- OK. !Pump 50 bbls Alpha Spacer @ 10.3 ppg. Pump 190 sxs (39 bbls) 15.9 ppg Class G Premium with 1% Halad 344 + 0.2% CFR3 + 0.4% HR5 + 0.25 pps of Super CBL. 09:30 - 10:30 1.00 CASE P PROD1 Switch to rig and diplace dart @ -9 bpm to wiper plug and bump with 207.8 bbls (2431 stks -- 97% pump eft.). Increase press to 3500 psi & hold for 2 minutes. Release press & ck floats -- OK. Release from liner hanger. 10:30 - 11:30 1.00 CASE P PROD1 Circ cement above liner to surface while reciprocating 35 stokes and pumping @ 14 bpm. Estimated ~8 bbls of cement to surface. Note: Experienced a process leak when cement arrived at surface, the flowline was shut and divert line opened to the trough causing the fluid level to back up in the bell nipple, drip pan, and pipe set back. About 3/4 bbl of drilling fluid spilled over into the cellar -- all contained on herculite and clean up. 11:30 - 12:30 1.00 CASE P PROD1 Monitor well -- static. Pump dry job. Blow down cement line. Break down cement head. 12:30 - 13:00 0.50 CASE P PROD1 Blow down top drive and mud lines. PJSM -- Tugger riding. Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 21 of 23 Operations Summa Report Legal Well Name: N831 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/28/2001 13:00 - 14:00 1.00 CASE P PROD1 Service Top Drive. 14:00 - 17:30 3.50 CASE P PROD1 Monitor well -- Static. POOH with liner setting tool. 17:30 - 18:00 0.50 CASE P PROD1 Make service breaks in Baker liner setting tool and lay down. 18:00 - 20:00 2.00 CASE 3 PROD1 PJSM, Close Blind Rams and Test Liner and Lap to 3450 psi for 30 minutes with 9.3 ppg mud in the hole -- Good Test! Blow down lines. 20:00 - 23:00 3.00 CASE ~ PROD1 PJSM -- MU BHA 8 -- Casing/Liner Clean Out Assembly. PU and drift 4" dp out of pipe shed. 23:00 - 00:00 1.00 CASE ~ PROD1 Rill with 5" drill pipe. 5/29/2001 00:00 - 03:00 3.00 CASE ~ PROD1 Finish Rill with clean out assy on 5" dp. 03:00 - 04:30 1.50 CASE ~ PROD1 Wash up to 7" liner FC @ 11350' md. Notes: 1) Circ 14 bpm, Rotate 60 rpm, Reciprocate 35' for 10,000 stks (1.3 hole volumes) to condition mud in preparation for displacement. 2) AV in 4" x 7" is 650 fpm & AV in 5" x 9-5/8" is 300 fpm. 104:30 - 07:00 2.50 CASE ~ PROD1 PJSM -- Displace mud from well with unfiltered sea water. Notes: 1) Unfiltered sea water out of pipe rack measures 5 NTU. ~2) Circ 14 bpm, Rotate 60 rpm, Reciprocate 35' for 10,000 stks (800 bbls or 1.3 hole volumes). 3) Return sea water after mud displaced measured 198 NTU. 4) Mud in hole: PU 285K, SO 275 K and Torq is 4000 ft. lbs. 5) Brine in hole: PU 300K, SO 285 K and Torq is 6000 ft. lbs. 6) Circ 1160 bbls additional and NTU reduced to 100 units. 07:00 - 10:30 3.50 CASE P PROD1 RU to reverse circulate with Annular and top rams closed. Notes: 1) Monitor well with underbalanced sea water in hole to perform negative pressure test on liner and liner top -- hole static. 2) Wait for G&I to inject returned mud and brine to provide pit capacity to continue displacement of well with clean sea water as per program. 3) Refill G&I suction pit with sea water while injecting. 10:30 - 12:00 1.50 CASE P PROD1 Reverse circulate well unfiltered sea water out of pipe rack (NTU measures 5). 1) 14 bpm @ 1700 psi for 855 bbls. 2) NTU of sea water returns decreased f/100 to 55 units. 12:00 - 13:30 1.50 CASE P PROD1 Refill G&I pit with sea water & monitor well -- static. Note: Inject sea water returns in parallel with this operation. 13:30 - 14:00 0.50 CASE P PROD1 PJSM for casing wash -- discuss hazards of Caustic Wash and BARAKLEAN solvent and precautions to prevent exposure of personnel to these products and sweeps. 14:00 - 16:00 2.00 CASE P PROD1 Pump 50 bbls castic wash (sea water + 5 ppb caustic), 50 bbls BARAKLEAN FL solvent mix (sea water + 1 drum BARAKLEAN FL) and 50 bbls HI-VIS sweep (sea water + BARAZAN PLUS to 70YP). 16:00 - 18:00 2.00 CASE P PROD1 Circulate sweeps through out hole and measure NTU reading: Notes: 1) Total circulation 1410 bbls -- 40 NTU, 1453 bbls -- 54 NTU and 1881 bbls 64 NTU. 2) Shut down to inject and refill sea water. 18:00 - 20:00 2.00 CASE P PROD1 Injecting returns from sweeps and displacements. Notes: Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 22 of 23 Operations Summar Report Legal Well Name: N831 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/29/2001 18:00 - 20:00 2.00 CASE P i PROD1 1) Discussed inc NTU readings with Mud Engineer -- decision to send last two samples to Baroid plant for direct solids content measurements. 2) In meantime continue to inject sea water and build up stock of filtered sea water in G&I if more circulation is necessary. 20:00 - 23:30 3.50 CASE P PROD1 Building filtered sea water volume and injecting returned sea water. Note: Called ODE to discuss options: 1) Quit now call it good, 2) wait for reading from Baroid plant and 3) continue circulation and meauring NTU. Decision to see what Baroid measurements of actual solids reveal -- build filtered sea water volume and inject in parallel. 23:30 - 00:00 0.50 CASE P PROD1 RD pump in sub and LD 2 pups and 1 joint of 5" dp in )reparation to POOH. MISSION ACCOMPLISHED! Note: Baroid results revealed that the 54 NTU reading sample measured 36 mg/I solids content and the 64 NTU sample measured 54.5 mg/I solids. 5/30/2001 00:00 - 02:00 2.00 RUNCOI~!~ COMP PJSM. Clean out trip tank and flush pump. Fill with filtered seawater. Monitor well. 02:00 - 02:30 0.50 RUNCOr~ COMP POOH from 11,296' - 10,726' 02:30 - 04:00 1.50 RUNCOr~ COMP PJSM. Cut and slip driling line. Adjust brakes. 04:00 - 08:00 4.00 RUNCOI~' COMP POOH with drillpipe. 08:00 - 09:00 1.00 RUNCOI~ COMP PJSM. LD BHA. 09:00 - 09:30 0.50 RUNCOI~ COMP Clean rig floor. Pull wear bushing. 09:30 - 10:30 1.00 RUNCOI~ COMP PJSM -- Rig up to run the 7" 13CR completion. 10:30 - 11:00 0.50 RUNCOI~ COMP PJSM -- Run the 7" 13CR completion. 11:00 - 00:00 13.00 RUNCOI~ COMP RIH with 7" 13CR completion. Note: 1. Found a bad box on joint 32 while still in the pipeshed. Replacd. 2. Layed down two joints while running for galled threads. Replaced one box (Jr #6 replaced). 3. Take special care to dope the entire threads on the pin end to reduce thread interference, MU as far as possible by hand, then chain tong to resistance and hydraulic tong with torque turn. 5/31/2001 00:00 - 06:00 6.00 RUNCOI~P COMP RIH with 7" 29#, 13CR tubing. Ran joints #156 - #220. 06:00 - 06:30 0.50 RUNCOI~ COMP Clear rig floor and pick up control line equipment. 06:30 - 07:00 0.50 RUNCO~/P COMP PJSM. NAD processes reviewed; hoisting personnell and rig up. 07:00 - 08:30 1.50 RUNCOI~ COMP 'RU dual control lines for SLVN. 08:30 - 09:00 0.50 RUNCO~/P I COMP Test control lines to 5000 psi for 30 minutes. Test ok. 09:00 - 11:30 2.50~ RUNCO~ ~ COMP RIH with 7", 29#, 13CR tubing with control lines. Clamed contro lines to tubing. Ran joints #221 - #242. 11:30 - 12:00 0.50 RUNCO~' COMP Change out from 125 ton elevators to 200 ton elevators. 12:00 - 12:30 0.50 RUNCO~/P COMP PJSM. 12:30 - 16:30 4.00 RUNCO~ COMP Finish RIH with 7", 29# 13CR tubing with control lines. Ran 'joints #242 - #272. 16:30 - 17:30 1.00 RUNCO~/P COMP Space out for hanger. Added 2' pup below top joint of tubing for spaceout. 17:30 - 18:00 0.50 RUNCO~ F' COMP PJSM - MU hanger and landing joint. Printed: 6/4/2001 1:23:47 PM BP EXPLORATION Page 23 of 23 Operations Summa Report Legal Well Name: N831 Common Well Name: NS31 Spud Date: 4/26/2001 Event Name: DRILL+COMPLETE Start: 4/15/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: Date From - TO Hours ActivityCode NPT Phase Description of Operations 5/31/2001 18:00 - 20:00 2.00 RUNCOI~ COMP Run control lines through hanger and test same to 5000 psi. Test ok. 20:00 - 20:30 0.50 RUNCOr~ COMP Land 7" hanger. 20:30 - 21:00 0.50 RUNCOI~ COMP PJSM. Energize hanger with LDS and test to 6500 psi for 10 minutes. Test ok. 21:00 - 21:30 0.50 RUNCOr~ COMP Cut control lines at floor and RD HES. 21:30 - 22:00 0.50 RUNCOI~ COMP PJSM - Set TWC valve. 22:00 - 23:30 1.50 RUNCOI~ COMP PJSM - Pull mouse hole, floor plate, riser, and turnbuckles. 23:30 - 00:00 0.50 RUNCO~ COMP ND BOPs 6/1/2001 00:00 - 0.00 RUNCOI~ COMP 0.00 RUNCO~4 COMP 0.00 RUNCO~I COMP 0.00 RUNCOI~ COMP 0.00 RUNCO~/I COMP 0.00 RUNCO~ COMP 0.00 RUNCO~ COMP - 0.00 RUNCOI~ COMP 0.00 RUNCO~ COMP - 0.00 RUNCOr COMP - 0.00 RUNCOr COMP - 0.00 RUNCOIt COMP - 0.00 RUNCOIt COMP - 0.00 RUNCOI~ COMP 6/2/2001 00:00 - 01:00 1.00 RUNCOI~P COMP Continue to ND BOPs. 01:00 - 02:00 1.00 RUNCOItP COMP Set BOPs on ground and tie off. 02:00 - 03:00 1.00 RUNCOIt~ COMP PJSM - NU completion tree and run control lines through the tubing head and test to 5000 PSI. 03:00 - 07:30 4.50 RUNCOI~ COMP PJSM - NU completion tree. Test control lines to 5000 psi for 10 minutes. Test ok. Install 1502 companion sweep on annulus. Test tree to 6500 psi. 07:30 - 10:00 2.50 RUNCOr~ COMP Change out 2 packing gland nuts on wellhead. Test to 6,500 PSI. OK 10:00 - 12:00 2.00 RUNCOI~ COMP RU circulating manifold to U-tube annulus and tubing. 12:00 - 15:00 3.00 RUNCOI~ ~COMP PJSM - Test lines on manifold to 4500 psi. Change out fitting on tree cap and grease valves. 15:00 - 18:00 3.00 RUNCOI~ COMP Pump 26 bbls of seawater with corrosion inhibitor and 160 bbls of diesel for freeze protection. Clear lines with 15 bbls of seawater poumping down the 7"x 9 5/8" annulus. 18:00 - 18:30 0.50 RUNCOI~ COMP U-Tube freeze protection fluid from annulus to tubing. 18:30 - 20:00 1.50 RUNCOI~ COMP Drop ball to set the packer. Test the tubing and packer to 4500 psi for 30 minutes. Test ok. Bleed tubing pressure to 2000 psi. 20:00 - 20:30 0.50 RUNCOI~ COMP RU Halliburton. Test the 7" x 9 5/8" annulus to 5500 psi for 30 minutes. Test OK. 20:30 - 21:30 1.00 RUNCOI~ COMP RD Halliburton. Blow down Halliburton lines. 21:30 - 22:30 1.00 RUNCOI~ COMP Set BP¥. 22:30 - 00:00 1.50 RUNCOI~ COMP RD test manifold and lines. Printed: 6/4/2001 1:23:47 PM ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration (Alaska) Inc. Field .................... : Northstar Well ..................... : NS31 API number ............... : 50-029-23009-00 Engineer ................. : Leafstedt Rig: ..................... : Nabors 33E ~State: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 15.67 ft KB above permanent ....... : N/A DF above permanent ....... : 56.00 ft Vertical section origin Latitude (+N/S-) ......... Departure (+E/W-) ........ : 0.00 ft 0.00 ft - .... Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 52.23 degrees 23-May-2001 05:49:42 Page 1 of 6 Spud date ................ : 26-Apr-01 Last survey date ......... : 23-May-01 Total accepted surveys...: 124 MD of first survey ....... : 0.00 ft MD of last survey ........ : 11440.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 20-Apr-2001 Magnetic field strength..: 1149.79 HCNT Magnetic dec (+E/W-) ..... : 26.81 degrees Magnetic dip ............. : 80.91 degrees MWD survey Reference Criteria Reference G .............. : 1002.69 mGal Reference H .............. : 1149.79 HCNT Reference Dip ............ : 80.91 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections .dec (+E/W-) ..... : 26.81 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 26.81 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 23-May-2001 05:49:42 Page 2 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 50.00 0.10 285.80 3 100.00 0.20 27.30 4 150.00 0.40 24.60 5 200.00 0.40 14.10 TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 0.00 0.00 0.00 0.00 0.00 50.00 50.00 -0.03 0.01 -0.04 50.00 100.00 0.03 0.10 -0.04 50.00 150.00 0.26 0.34 0.07 50.00 200.00 0.55 0.67 0.18 6 300.00 0.60 35.20 100.00 7 361.00 0.50 47.80 61.00 8 453.00 0.70 88.50 92.00 9 544.00 1.50 102.10 91.00 10 634.00 2.00 97.80 90.00 11 724.00 2.60 90.70 12 754.32 2.77 86.41 13 845.09 3.44 90.82 14 936.56 4.37 89.40 15 1026.45 5.21 91.16 16 1118.23 4.76 86.60 17 1213.35 4.21 91.45 18 1307.86 5.04 93.22 19 1402.64 4.62 91.85 20 1497.41 4.86 96.58 21 1591.33 3.69 88.66 22 1687.08 3.53 95.33 23 1781.56 3.55 95.76 24 1875.62 2.67 87.24 25 1971.29 0.91 46.68 90.00 30.32 90.77 91.47 89.89 91.78 95.12 94.51 94.78 94.77 93.92 95.75 94.48 94.06 95.67 94.05 94.64 94.25 95.76 94.89 26 2065.34 0.89 46.68 27 2159.98 0.94 48.61 28 2254.23 1.06 55.64 29 2349.99 0.34 64.99 30 2444.88 0.35 77.00 299.99 1.33 1.43 0.57 360.99 1.90 1.87 0.95 452.99 2.75 2.16 1.81 543.97 3.97 1.92 3.53 633.93 5.83 1.46 6.24 DLS (deg/ iOOf) Srvy tool type 0.00 0o00 0.00 TIP 0.04 285.80 0.20 GYR 0.11 336.55 0.48 GYR 0.34 11.51 0.40 GYR 0.69 15.45 0.15 GYR 1.54 21.73 0.27 GYR 2.10 26.96 0.26 GYR 2.82 40.03 0.50 GYR 4.02 61.46 0.92 GYR 6.41 76.82 0.57 GYR 0.74 0.87 0.78 1.02 0.95 723.85 8.52 1.22 9.84 9.91 82.91 754.14 9.67 1.26 11.26 11.33 83.61 844.78 13.61 1.36 16.17 16.22 85.20 936.03 18.53 1.36 22.40 22.44 86.54 1025.61 24.44 1.31 29.90 29.93 87.49 1117.04 30.82 1.45 37.87 37.90 87.81 0.65 1211.87 36.79 1.60 45.30 45.33 87.98 0.70 1306.07 42.61 1.28 52.91 52.93 88.62 0.89 1400.52 48.69 0.92 60.88 60.89 89.14 0.46 1494.96 54.50 0.33 68.69 68.69 89.72 0.48 1588.62 1684.18 1778.48 1872.40 1968.02 GYR MWD MWD MWD MWD MWD MWD MWD MWD MWD 59.78 -0.05 75.66 64.41 -0.25 81.68 68.65 -0.82 87.48 72.56 -1.00 92.57 75.14 -0.37 95.35 76.61 0.64 96.42 78.12 1.66 97.54 79.76 2.66 98.84 80.92 3.28 99.83 81.46 3.46 100.36 2062.06 2156.69 2250.93 2346.68 2441.57 75.66 90.04 1.39 MWD 81.68 90.18 0.47 MWD 87.49 90.53 0.04 M~ 92.57 90.62 1.05 MWD 95.35 90.22 2.16 MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 96.42 89.62 0.02 M~JD 6-axis 97.55 89.03 0.06 MWD 6-axis 98.87 88.46 0.18 MB~ 6-axis 99.88 88.12 0.76 M~ 6-axis 100.42 88.02 0.08 MBJD - [(c)2001 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey Report 23-May-2001 05:49:42 Page 3 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 2538.06 0.37 72.64 32 2635.20 0.37 70.39 33 2726.13 0.35 76.20 34 2821.98 0.31 67.94 35 2917.54 0.32 71.92 36 3012.81 0.29 85.54 37 3106.71 0.22 80.77 38 3177.82 0.17 91.24 39 3292.18 0.18 66.03 40 3387.21 0.36 41.28 41 3587.80 0.51 55.12 42 3671.78 0.59 60.27 43 3766.60 0.47 53.84 44 3860.78 0.51 52.27 45 3955.94 0.56 61.23 46 4051.50 0.37 57.90 47 4143.31 0.37 67.55 48 4236.98 0.37 60.65 49 4330.53 0.52 72.93 50 4426.76 0.27 98.87 51 4519.86 0.29 97.88 52 4614.20 0.15 122.78 53 4709.12 0.15 88.06 54 4803.96 0.17 87.78 55 4898.41 0.23 103.89 56 4992.72 0.11 93.41 57 5086.85 0.09 74.14 58 5180.87 0.00 26.81 59 5275.93 0.28 350.25 60 5368.79 0.18 13.15 93.18 97.14 90.93 95.85 95.56 95.27 93.90 71.11 114.36 95.03 200.59 83.98 94.82 94.18 95.16 95.56 91.81 93.67 93.55 96.23 93.10 94.34 94.92 94.84 94.45 94.31 94.13 94.02 95.06 92.86 TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) i00f) type type 2534.74 2631.88 2722.81 2818.66 2914.22 3009.49 3103.38 3174.49 3288.85 3383.88 3584.47 3668.44 3763.26 3857.44 3952.59 4048.15 4139.96 4233.62 4327.17 4423.40 82.00 3.62 100.93 100.99 87.95 82.59 3.82 101.52 101.60 87.85 83.12 3.98 102.07 102.15 87.77 83.64 4.15 102.59 102.68 87.68 84.14 4.33 103.09 103.18 87.60 84.59 4.43 103.58 103.68 87.55 84.95 4.48 104.00 104.09 87.53 85.15 4.50 104.24 104.33 87.53 85.46 4.57 104.57 104.67 87.50 85.90 4.85 104.90 105.02 87.35 87.41 5.84 106.05 106.21 86.85 88.21 6.26 106.73 106.92 86.64 89.08 6.74 107.47 107.68 86.41 89.88 7.22 108.12 108.36 86.18 90.77 7.70 108.86 109.13 85.95 91.54 8.09 109.53 109.83 85.77 92.12 8.36 110.05 110.37 85.65 92.71 8.63 110.60 110.93 85.54 93.40 8.90 111.27 111.62 85.43 93.97 8.99 111.91 112.27 85.41 4516.50 94.28 8.93 4610.84 94.49 8.83 4705.76 94.63 8.76 4800.60 94.85 8.77 4895.05 95.08 8.73 4989.35 5083.48 5177.50 5272.56 5365.42 112.36 112.70 112.93 113.19 113.52 112.71 113.04 113.27 113.53 113.85 85.46 85.52 85.56 85.57 85.60 95.27 8.68 113.79 114.12 85.64 95.40 8.70 113.95 114.28 85.64 95.47 8.72 114.02 114.35 85.63 95.58 8.95 113.98 114.33 85.51 95.80 9.31 113.98 114.36 85.33 0.04 0.01 0.05 0.06 0.03 0.08 0.08 0.09 0.07 0.22 0.09 0.11 0.14 0.04 0.10 0.20 0.07 O.O5 0.19 0.31 0.02 0.18 0.09 0.02 0.09 0.13 0.04 0.10 0.29 0.14 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 23-May-2001 05:49:42 Page 4 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 5464.12 0.10 22.36 62 5557.38 0.21 238.61 63 5653.60 0.40 305.85 64 5746.91 0.27 284.79 65 5841.62 0.27 252.14 95.33 93.26 96.22 93.31 94.71 66 5937.71 0.29 256.76 67 6031.84 0.12 244.36 68 6127.22 0.15 280.72 69 6222.73 0.14 247.69 70 6316.08 0.26 273.04 96.09 94.13 95.38 95.51 93.35 71 6412.74 0.31 252.32 72 6506.08 0.40 276.48 73 6599.54 0.28 279.40 74 6694.95 0.41 282.62 75 6788.42 0.46 283.15 96.66 93.34 93.46 95.41 93.47 76 6882.81 0.40 280.25 77 7086.26 0.46 281.24 78 7269.75 0.49 284.40 79 7364.87 0.73 34.26 80 7459.05 2.77 53.66 TVD Vertical Displ Displ Total depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) 81 7552.45 3.85 57.15 82 7647.65 4.47 50.91 83 7742.75 5.98 46.82 84 7836.59 7.29 51.02 85 7931.98 9.05 52.66 5460.75 5554.01 5650.23 5743.54 5838.25 95.99 9.53 95.89 9.52 95.62 9.63 95.39 9.87 95.05 9.86 5934.34 94.61 9.74 6028.47 94.30 9.64 6123.85 94.12 9.62 6219.36 93.92 9.60 6312.71 93.65 9.57 6409.37 93.24 9.50 6502.70 92.77 9.46 6596.16 92.38 9.53 6691.57 92.01 9.64 6785.04 91.56 9.80 114.04 113.93 113.50 113.03 112.60 112.15 111.83 111.61 111.38 111.07 110.60 110.03 109.48 108.92 108.23 94.39 6879.42 91.10 9.95 107.54 203.45 7082.87 90.09 10.23 106.04 183.49 7266.35 89.12 10.57 104.55 95.12 7361.47 89.45 11.17 104.50 94.18 7455.60 92.30 13.02 106.67 93.40 7548.84 97.68 16.06 111.13 95.20 7643.79 104.57 20.13 116.69 95.10 7738.50 113.21 25.86 123.18 93.84 7831.71 124.03 32.95 131.37 95.39 7926.12 137.58 41.31 142.04 86 8025.67 11.15 50.92 93.69 8018.36 154.01 51.49 154.93 87 8120.84 13.29 47.93 95.17 8111.37 174.12 64.62 170.20 88 8215.37 15.52 47.47 94.53 8202.92 197.56 80.45 187.59 89 8309.57 17.81 49.55 94.20 8293.16 224.51 98.32 207.84 90 8403.78 19.95 52.11 94.21 8382.29 254.98 117.54 231.49 At Azim (deg) 85.22 85.22 85.15 85.01 85.00 114.44 114.32 113.91 113.46 113.03 112.57 112.24 112.03 111.80 111.48 111.01 110.44 109.90 109.35 108.67 108.00 106.53 105.09 105.10 107.46 112.28 118.41 125.86 135.44 147.93 163.26 182.05 204.11 229.92 259.62 85.04 85.07 85.07 85.08 85.08 85.09 85.09 85.02 84.94 84.82 84.71 84.49 84.23 83.90 83.04 81.78 80.21 78.15 75.92 73.79 71.62 69.21 66.79 64.68 63.08 DLS ( deg/ lOOf) 0.09 0.32 0.39 0.19 0.16 0.03 0.19 0.09 0.09 0.16 0.12 0.19 0.13 0.14 0.05 0.07 0.03 0.02 1.06 2.23 1.18 0.81 -1.63 1.49 1.86 2.26 2.34 2.36 2.51 2.44 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 23-May-2001 05:49:42 Page TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 91 8498.33 21.98 51.23 94.55 8470.58 288.80 138.53 258.02 292.85 61.77 92 8592.65 23.32 49.66 94.32 8557.63 325.11 161.67 286.01 328.54 60.52 93 8688.33 23.85 49.75 95.68 8645.31 363.35 186.42 315.21 366.21 59.40 94 8782.55 24.40 49.55 94.22 8731.30 401.82 211.36 344.56 404.22 58.47 95 8878.41 23.42 49.31 95.86 8818.94 440.63 236.63 374.07 442.63 57.68 96 8973.50 22.72 49.08 95.09 8906.42 477.84 260.97 402.28 479.52 57.03 97 9067.50 22.33 49.36 94.00 8993.25 513.80 284.50 429.55 515.21 56.48 98 9161.34 21.98 50.00 93.84 9080.16 549.15 307.39. 456.53 550.37 56.05 99 9254.84 21.34 50.04 93.50 9167.06 583.63 329.57 482.97 584.70 55.69 100 9348.88 20.36 49.41 94.04 9254.94 617.07 351.20 508.51 618.00 55.37 101 9444.92 19.84 49.43 96.04 9345.13 650.04 372.67 533.58 650.84 55.07 102 9540.77 19.32 49.17 95.85 9435.44 682.12 393.62 557.93 682.80 54.80 103 9634.50 18.56 49.22 93.73 9524.09 712.50 413.50 580.96 713.09 54.56 104 9729.24 17.94 49.41 94.74 9614.07 742.13 432.84 603.45 742.63 54.35 105 9822.76 17.46 48.18 93.52 9703.16 770.51 451.57 624.85 770.94 54.14 95.29 9794.21 798.53 470.42 645.69 798.88 53.92 94.06 9884.31 825.45 488.67 665.61 825.73 53.71 94.73 9975.23 851.94 506.71 685.14 852.16 53.51 95.23 10066.88 877.68 524.38 704.01 877.84 53.32 95.32 10158.91 902.36 541.61 721.88 902.47 53.12 93.50 95.28 94.44 94.63 91.37 10249.41 925.72 557.95 738.77 925.79 52.94 10341.94 948.32 573.48 755.32 948.37 52.79 10434.06 969.06 587.70 770.55 969.09 52.67 10526.65 988.53 601.06 784.82 988.54 52.55 10616.28 1006.14 613.20 797.70 1006.15 52.45 106 9918.05 16.85 47.56 107 10012.11 16.53 47.43 108 10106.84 16.07 47.13 109 10202.07 15.43 46.61 110 10297.39 14.77 45.44 57.17 10672.48 1016.60 620.22 805.49 1016.61 78.22 10749.44 1030.61 629.13 816.31 1030.62 96.00 10843.92 1047.57 639.90 829.43 1047.58 95.00 10937.53 1063.77 650.40 841.77 1063.77 95.00 11031.25 1079.29 660.69 853.44 1079.29 111 10390.89 14.34 46.46 112 10486.17 13.23 47.23 113 10580.61 12.25 46.68 114 10675.24 11.60 47.07 115 10766.61 10.74 46.30 116 10823.78 10.41 49.82 117 10902.00 10.24 51.20 118 10998.00 10.12 50.03 119 11093.00 9.53 49.17 120 11188.00 9.32 48.03 52.40 52.38 52.35 52.31 52.26 5 of 6 DLS (deg/ 100f) 2.17 1.56 0.56 0.59 1.03 0.74 0.43 0.45 0.68 1.07 0.54 0.55 0.81 0.66 0.65 0.67 0.34 0.49 0.69 0.76 0.54 1.18 1.05 0.69 0.96 1.27 0.38 0.25 0.64 0.30 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD GYR GYR GYR GYR Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -- 6-axis 6-axis -- -- -- [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 23-May-2001 05:49:42 Page 6 of 6 Seq Measured Incl Azimuth ~ depth angle angle - (ft) (deg) (deg) 121 11283.00 8.93 47.65 122 11378.00 8.36 47.39 123 11421.00 7.85 48.19 Course length (ft) TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) Projection to Total Depth: 124 11440.00 7.62 48.55 95.00 11125.05 1094.31 670.80 864.61 95.00 11218.97 1108.55 680.44 875.14 43.00 11261.54 1114.59 684.51 879.63 19.00 DLS (deg/ 100f) Srvy tool type 1094.31 52.19 0.42 GYR 1108.55 52.13 0.60 GYR 1114.59 52.11 1.21 GYR 1.24 11280.36 1117.14 686.21 881.54 1117.14 52.10 Proj Tool qual type [(c)2001 Anadrill IDEAL ID6_iC_08] /~o~ c-c- WELL NO. NS-31 NORTHSTAR FIEELD, ALASKA, Gyro, Mu~tishot'iriSiC~e 5" ~ri~lpipe $u~¥ date' '5/~"/01 00:05/kb1 Job number ..AK50550T gyr data B.P. EXPLORATION WELL NO. NS-31 NORTHSTAR FIELD, ALASKA G'~:r0'M'u'ifis fi6t 'in'~!.'..de'' 5.'"'d.rillpipe survey date' 5/21/01 00:03 AM Job number :AK505507 gyro/data CONTENTS JOB NUMBER :AK505507 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT gyr~data 1. DISCUSSION , SURVEY CERTIFICATION SHEET gyreCdata DISCUSSION JOB NUMBER' AK505507 Tool 813 was run in NS-31 as a drop multishot. The survey was completed without any problems. gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK505507 .The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- WALTER KILEY OPERATIONS MANAGER gyr~data 2. SURVEY DETAILS gyro/data SURVEY DETAILS JOB NUMBER: AK505507 CLIENT: B.P. EXPLORATION RIG: NABORS 33E LOCATION: NORTHSTAR WELL: NS-31 LATITUDE: 70.495 N LONGITUDE: 148.600 E SURVEY DATE: 5/21/01 00:03 SURVEY TYPE : DROP MULTISHOT DEPTH REFERENCE: ROTARY TABLE ELEVATION MAX. SURVEY DEPTH: 11421.0 SURVEY TIED ONTO: SURVEY INTERVAL: Overlap 0.0 UTM CO-ORDINATES: TARGET DIRECTION: 52.23 GRID CORRECTION: 0.00 CALCULATION METHOD: Minimum Curvature SURVEYOR: Tom Stoddard gyro/data 3. OUTRUN SURVEY LISTING A Gyrodata Directional Survey for B.P. Exploration Well: NS-31, 5" DRILLPIPE Location: NABORS 33E, NORTHSTAR Job Number: AK505507 Run Date: 5/21/01 8:47:11 AM Surveyor: Tom Stoddard Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.495000 deg. N Sub-sea Correction from Vertical Reference: 55.77 ft. Azimuth Correction: Gyro: Bearings are Relative to Tree North Proposed Well Direction: 52.230 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location I lorizontal Coordinates Calculated fi-om Well }lead IJocation B.P. Exploration Well: NS-31, 5" DRILLPIPE Location: NABORS 33E, NORTHSTAR Job Number: AK505507 MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 0.0 0.00 0.00 0.00 91.1 0.18 52.92 0.20 182.2 0.25 49.14 0.07 273.3 0.25 41.21 0.04 364.3 0.32 54.88 0.11 455.4 0.50 80.25 0.28 546.5 0.91 97.94 0.51 637.6 1.42 102.98 0.57 728.1 2.39 94.90 1.11 819.2 2.92 91.77 0.60 913.7 3.83 93.09 1008.3 4.54 91.48 1102.9 4.97 90.97 1197.5 4.66 91.84 1292.1 4.72 92.34 0.97 0.75 0.46 0.34 0.07 1386.6 4.99 93.88 0.32 1481.2 4.82 95.98 0.26 1575.8 4.36 94.12 0.51 1670.4 3.69 95.04 0.70 1765.0 3.77 95.49 0.09 1859.5 3.35 92.86 0.48 1954.1 1.69 72.62 1.96 2048.7 0.97 56.98 0.85 2143.3 1.01 56.25 0.04 2237.8 1.07 57.65 0.07 A Gyrodata Directional Survey VERTICAL SUB SEA VERTICAL DEPTH DEPTH SECTION feet feet feet CLOSURE DIST. AZIMUTH feet deg. 0.0 -55.8 0.0 91.1 35.3 0.1 182.2 126.4 0.5 273.3 217.5 0.9 364.3 308.6 1.3 455.4 399.7 1.9 546.5 490.7 2.8 637.6 581.8 4.0 728.1 672.3 6.1 819.0 763.2 9.3 913.4 857.6 13.6 1007.7 952.0 18.8 1102.0 1046.2 24.9 1196.2 1140.5 31.1 1290.5 1234.7 37.0 0.0 0.0 0.1 52.9 0.5 51.4 0.9 48.6 1.3 48.7 1.9 2.9 4.6 7.5 11.7 17.3 24.2 32.0 40.0 47.7 1384.7 1329.0 43.1 55.7 1479.0 1423.2 49.0 63.8 1573.2 1517.5 54.6 71.3 1667.6 1611.8 59.5 78.0 1762.0 1706.2 64.0 84.1 1856.3 1800.6 68.3 1950.8 1895.1 71.7 2045.4 1989.6 73.9 2140.0 2084.2 75.5 2234.5 2178.8 77.2 90.0 94.1 96.0 97.4 98.8 55.7 68.7 81.1 87.8 89.7 90.6 91.1 91.1 91.2 91.3 91.6 92.0 92.3 92.5 92.7 92.8 92.5 92.0 91.4 90.8 HORIZONTAL COORDINATES feet 0.00 N 0.09 N 0.31 N 0.58 N 0.88 N 1.09 N 1.06 N 0.71 N 0.29 N 0.06 N 0.19 S 0.45 S 0.62 S 0.81 S 1.09 S 1.53 S 2.22 S 2.89 S 3.42 S 3.98 S 4.42 S 4.14 S 3.29 S 2.39 S 1.45 S 0.00 0.12 0.38 0.66 1.00 1.60 2.72 4.54 7.52 11.73 17.29 24.19 32.03 39.97 47.70 55.69 63.74 71.28 77.89 84.03 89.88 93.97 95.97 97.34 98.78 '2 B.P. Exploration Well: NS-31, 5" DRILLPIPE Location: NABORS 33E, NORTHSTAR Job Number: AK505507 MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. A Gyrodata Directional Survey VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2332.4 0.92 61.87 0.18 2427.0 0.47 83.65 0.55 2521.6 0.42 85.64 0.05 2616.2 0.44 86.10 0.02 2710.7 0.41 87.92 0.03 2805.3 0.37 89.54 0.04 2899.9 0.35 91.29 0.02 2994.5 0.37 90.10 0.02 3089.1 0.29 97.76 0.10 3183.6 0.13 102.38 0.17 3278.2 0.15 91.39 0.04 3372.8 0.20 63.28 0.10 3467.4 0.19 51.84 0.04 3561.9 0.30 52.71 0.11 3656.5 0.37 51.17 0.08 3751.1 0.45 50.48 0.08 3845.7 0.47 54.47 0.04 3940.3 0.46 57.38 0.02 4034.8 0.47 57.97 0.01 4129.4 0.37 58.25 0.10 4224.0 0.38 62.98 0.03 4318.6 0.37 62.05 0.01 4413.1 0.27 85.30 0.18 4507.7 0.27 71.54 0.07 2329.1 2273.3 78.8 2423.6 2367.9 79.9 2518.2 2462.5 80.5 2612.8 2557.0 81.1 2707.4 2651.6 81.7 2801.9 2746.2 82.2 2896.5 2840.8 82.7 2991.1 2935.3 83.2 3085.7 3029.9 83.6 3180.3 3124.5 83.8 3274.8 3219.1 84.0 3369.4 3313.6 84.2 3464.0 3408.2 84.5 3558.6 3502.8 85.0 3653.1 3597.4 85.5 3747.7 3691.9 86.2 3842.3 3786.5 86.9 3936.9 3881.1 87.7 4031.4 3975.7 88.5 4126.0 4070.3 89.1 4220.6 4164.8 89.8 4315.2 4259.4 90.4 4409.7 4354.0 90.9 4504.3 4448.6 91.3 100.2 90.4 101.3 90.1 102.0 90.1 102.7 90.1 103.4 90.0 104.1 104.7 105.2 105.8 106.1 106.4 106.6 106.9 107.2 107.7 108.2 108.8 109.4 110.1 110.7 111.2 111.8 112.3 112.7 90.0 90.0 90.0 90.0 90.1 90.1 90.1 90.0 89.8 89.6 89.4 89.2 89.0 88.8 88.6 88.4 88.3 88.2 88.2 0.62 S 0.21 S 0.14 S 0.09 S 0.06 S 0.04 S 0.05 S 0.05 S 0.09 S 0.14 S 0.17 S 0.09 S O.08 N 0.33 N 0.67 N 1.09 N 1.55 N 1.98 N 2.39 N 2.75 N 3.06 N 3.34 N 3.51 N 3.59 N 100.20 E 101.26 E 101.99 E 102.70 E 103.40 E 104.05 E 104.65 E 105.25 E 105.79 E 106.13 E 106.36 E 106.63 E 106.90 E 107.22 E 107.66 E 108.18 E 108.78 E 109.41E 110.06 E 110.64 E 111.18 E 111.73 E 112.22 E 112.66 E B.P. Exploration Well: NS-31, 5" DRILLPIPE Location: NABORS 33E, NORTHSTAR Job Number: AK505507 A Gyrodata Directional Survey MEASUR]~D I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE DEPTIt SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet feet deg. 100 ft. 4602.3 0.19 61.26 0.09 4696.9 0.19 62.13 0.00 4791.4 0.21 64.01 0.03 4886.0 0.22 65.24 0.01 4980.6 0.22 47.23 0.07 5075.2 0.15 41.66 0.08 5169.8 0.21 11.58 5264.3 0.23 18.61 5358.9 0.23 16.84 5453.5 0.21 323.99 5548.1 0.30 301.12 5642.6 0.27 299.15 5737.2 0.26 296.43 5831.8 0.27 291.28 5926.4 0.24 295.18 6021.0 0.25 292.61 6115.5 0.27 289.13 6210.1 0.28 287.17 6304.7 0.29 156.09 6399.3 0.25 287.91 6493.9 0.26 286.59 0.11 0.04 0.01 0.21 0.14 0.03 0.02 0.03 0.04 0.02 0.02 0.02 0.55 0.52 0.02 0.03 0.09 0.03 6588.4 0.29 285.01 6683.0 0.38 286.36 6777.6 0.39 290.34 4598.9 4543.1 91.6 4693.5 4637.7 91.9 4788.1 4732.3 92.3 4882.6 4826.9 92.6 4977.2 4921.4 93.0 5071.8 5016.0 93.3 5166.4 5110.6 93.5 5260.9 5205.2 93.8 5355.5 5299.8 94.1 5450.1 5394.3 94.3 5544.7 5488.9 94.2 5639.2 5583.5 94.0 5733.8 5678.1 93.8 5828.4 5772.6 93.6 5923.0 5867.2 93.4 6017.6 5961.8 93.2 6112.1 6056.4 93.0 6206.7 6150.9 92.7 6301.3 6245.5 92.6 6395.9 6340.1 92.4 6490.5 6434.7 92.1 6585.0 6529.3 91.9 6679.6 6623.8 91.5 6774.2 6718.4 91.2 113.1 88.1 113.3 88.0 113.6 88.O 114.0 87.9 114.3 87.8 114.5 87.7 114.6 87.6 114.7 87.4 114.9 87.2 114.8 87.1 114.5 86.9 114.1 86.8 113.8 86.7 113.4 86.6 113.0 86.5 112.6 86.4 112.3 86.3 111.8 86.2 111.7 86.3 111.6 86.4 111.2 86.3 110.8 86.2 110.2 86.1 109.7 86.0 HORIZONTAL COORDINATES feet 3.74 N 3.89 N 4.04 N 4.19 N 4.39 N 4.60 N 4.86 N 5.21 N 5.57 N 5.89 N 6.16N 6.39 N 6.60 N 6.78 N 6.94 N 7.11 N 7.26 N 7.40 N 7.25 N 7.09 N 7.22 N 7.34 N 7.49 N 7.69 N 113.00 E 113.28 E 113.57 E 113.90 E 114.19 E 114.41 E 114.52 E 114.62 E 114.73 E 114.69 E 114.38 E 113.97 E 113.58 E 113.17 E 112.79 E 112.42 E 112.02 E 111.59 E 111.47 E 111.37 E 110.96 E 110.52 E 109.99 E 109.39 E B.P. Exploration Well: NS-31, 5" DRILLPIPE Location: NABORS 33E, NORTHSTAR Job Number: AK505507 A Gyrodata Directional Survey MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL DEPTH SEVERITY DEPTH DEPTH SECTION feet deg. deg. deg./ feet feet feet 100 ft. 6872.2 0.39 293.13 6966.8 0.48 299.64 0.02 0.11 0.10 0.12 0.29 0.11 1.68 7061.3 0.48 288.64 7155.9 0.52 301.59 7250.5 0.46 334.07 7345.1 0.46 -347.20 7439.6 1.77 47.59 6868.8 6813.0 90.9 6963.3 6907.6 90.5 7057.9 7002.1 90.2 7152.5 7096.7 89.8 7247.1 7191.3 89.7 7341.6 7285.8 90.0 7436.2 7380.4 91.6 7534.2 3.49 54.50 1.84 7530.6 7474.9 95.9 7628.8 4.19 53.81 0.74 7625.0 7569.2 102.2 7723.4 5.,14 46.25 1.48 7710.3 7663.5 ll0.1 7817.9 6.61 49.37 1.29 7813.3 7757.5 120.0 7912.5 8.37 51.65 1.88 7907.1 7851.3 132.4 8007.1 10.27 51.36 2.01 8000.4 7944.6 147.7 8101.7 12.50 49.68 2.39 8093.1 8037.3 166.3 8196.3 14.67 47.25 2.37 8185.0 8129.3 188.5 8290.8 16.97 48.98 2.49 8276.1 8220.3 214.2 8385.4 19.34 50.88 2.58 8365.9 8310.1 243.6 CLOSURE DIST. AZIMUTH feet deg. 8480.0 21.40 49.81 2.21 8454.6 8398.8 276.5 8574.6 23.60 48.89 2.36 8541.9 8486.2 312.7 8669.1 24.81 48.28 1.31 8628.2 8572.4 351.4 8763.7 24.21 49.25 0.77 8714.3 8658.5 390.5 8858.3 23.52 49.34 0.73 8800.7 8745.0 428.8 8952.9 22.79 49.87 0.81 8887.7 8831.9 465.9 9047.5 22.58 49.88 0.22 8975.0 8919.2 502.4 109.1 85.8 108.5 85.6 107.8 85.4 107.1 85.2 106.6 84.9 106.4 84.5 107.5 83.8 111.2 116.8 123.6 132.2 143.4 157.5 175.0 195.7 220.2 248.7 280.8 316.2 354.2 392.8 430.6 467.5 503.7 82.7 81.2 79.3 77.0 74.8 72.6 70.3 67.9 65.6 63.8 62.2 60.8 59.4 58.4 57.6 56.9 56.4 HORIZONTAL COORDINATES feet 7.93 N 8.26 N 8.58 N 8.93 N 9.49 N 10.19 N 11.55 N 14.20 N 17.91N 23.04 N 29.69 N 37.51N 47.O4 N 58.93 N 73.68 N 90.87N 109.82 N 130.83 N 154.41N 180.07 N 205.94 N 230.89 N 254.99 N 278.50 N 108.79 E 108.15 E 107.43 E 106.69 E 106.17 E 105.92 E 106.91E 110.33 E 115.46 E 121.48 E 128.85 E 138.38 E 150.36 E 164.75 E 181.35 E 200.56 E 223.13 E 248.46 E 275.90 E 3O4.99 E 334.50 E 363.50 E 391.82 E 419.71 E B.P. Exploration Well: NS-31, 5" DRILLPIPE Location: NABORS 33E, NORTHSTAR Job Number: AK505507 A Gyrodata Directional Survey MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL DEPTH SEVERITY DEPTH DEPTH SECTION feet deg. deg. deg./ feet feet feet 100 ft. 9142.0 22.00 49.47 0.63 9062.5 9006.7 538.2 9236.6 21.01 49.39 1.05 9150.5 9094.7 572.8 9331.2 20.36 49.79 0.70 9239.0 9183.2 606.2 9520.3 19.55 49.14 0.44 9416.7 9361.0 670.7 9614.9 19.11 49.33 0.48 9506.0 9450.2 701.9 9709.5 17.97 49.37 1.20 9595.7 9539.9 732.0 9804.1 17.46 47.11 0.90 9685.8 9630.0 760.7 9898.6 16.91 46.95 0.59 9776.1 9720.3 788.5 9993.2 16.58 46.79 0.35 9866.7 9810.9 815.6 10087.8 15.96 47.03 0.66 9957.5 9901.7 842.0 10182.4 15.38 46.72 0.62 10048.5 9992.8 867.4 10277.0 14.93 46.47 0.49 10139.8 10084.1 892.0 10371.5 13.99 46.99 1.00 10231.4 10175.6 915.6 10466.1 13.24 47.51 0.80 10560.7 12.85 47.18 0.42 10642.8 12.31 46.07 0.72 10712.1 11.55 46.46 1.11 10807.7 10.81 48.09 0.84 10902.3 10.24 51.20 0.85 10997.5 10.12 50.03 0.25 11092.6 9.53 49.17 0.65 11187.7 9.32 - 48.03 0.29 11282.9 8.93 47.65 0.42 11378.0 8.36 47.39 0.59 CLOSURE DIST. AZIMUTH feet deg. 539.3 56.0 573.8 55.6 6O7.0 55.3 671.3 702.5 732.4 761.0 788.8 815.8 842.2 867.6 892.1 915.6 10323.3 10267.5 937.7 937.8 10415.5 10359.7 959.0 959.0 10495.6 10439.8 976.8 976.8 10563.4 10507.6 991.1 991.1 10657.2 10601.4 1009.5 1009.5 10750.2 10694.4 1026.8 1026.8 10843.8 10788.1 1043.6 1043.6 10937.6 10881.8 1059.8 1059.8 11031.4 10975.7 1075.4 1075.4 11125.4 11069.6 1090.4 1090.4 11219.4 11163.6 1104.6 1104.7 54.7 54.5 54.3 54.0 53.8 53.5 53.3 53.2 53.0 52.8 52.7 52.6 52.4 52.4 52.3 52.2 52.2 52.2 52.1 52.0 52.0 HORIZONTAL COORDINATES feet 301.71N 324.25 N 345.90 N 387.85 N 408.30 N 427.88 N 447.05 N 466.09 N 484.72 N 502.83 N 520.29 N 537.28 N 553.47 N 568.59 N 583.05 N 595.33 N 605.24 N 617.82 N 629.02 N 639.69 N 650.21N 660.51N 670.63 N 680.29 N 447.07 E 473.40 E 498.83 E 547.90 E 571.61E 594.42 E 615.89 E 636.34 E 656.23 E 675.58 E 694.23 E 712.19 E 729.38 E 745.73 E 761.44 E 774.44 E 784.78 E 798.40 E 811.56 E 824.56 E 836.92 E 848.60 E 859.78 E 870.33 E B.P. Exploration Well: NS-31, 5" DRILLPIPE Location: NABORS 33E, NORTHSTAR Job Number: AK505507 MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 fi. 11421.0 7.85 48.19 1.22 Final Station Closure: Distance: 1110.71 ft Az: A Gyrodata Directional Survey VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet CLOSURE DIST. AZIMUTH feet deg. 11262.0 11206.2 1110.7 1110.7 52.0 51.96 deg. HORIZONTAL COORDINATES feet 684.36 N 874.82 E A Gyrodata Directional Survey for B.P. Exploration Well: NS-31, 5" DRILLPIPE Location: NABORS 33E, NORTHSTAR Job Number: AK505507SS Run Date: 5/21/01 8:47:11 AM Surveyor: Tom Stoddard Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.495000 deg. N Sub-sea Correction from Vertical Reference: 55.77 fi. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 52.230 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location B.P. Exploration Well: NS-31, 5" DRILLPIPE Location: NABORS 33E, NORTHSTAR Job Number: AK505507SS SUBSEA I N C L AZIMUTH DOGLEG DEPTIt SEVERITY feet deg. deg. deg./ 100 ft. -55.8 0.00 0.00 0.00 35.3 0.18 52.92 0.20 126.4 0.25 49.14 0.07 217.5 0.25 41.21 0.04 308.6 0.32 54.88 0.11 399.7 0.50 80.25 0.28 490.7 0.91 97.94 0.51 581.8 1.42 102.98 0.57 672.3 2.39 94.90 1.11 763.2 2.92 91.77 0.60 857.6 3.83 93.09 952.0 4.54 91.48 1046.2 4.97 90.97 1140.5 4.66 91.84 1234.7 4.72 92.34 0.97 0.75 0.46 0.34 0.07 1329.0 4.99 93.88 0.32 1423.2 4.82 95.98 0.26 1517.5 4.36 94.12 0.51 1611.8 3.69 95.04 0.70 1706.2 3.77 95.49 0.09 1800.6 3.35 92.86 0.48 1895.1 1.69 72.62 1.96 1989.6 0.97 56.98 0.85 2084.2 1.01 56.25 0.04 2178.8 1.07 57.65 0.07 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 0.0 0.0 0.0 0.0 91.1 0.1 0.1 52.9 182.2 0.5 0.5 51.4 273.3 0.9 0.9 48.6 364.3 1.3 1.3 48.7 455.4 1.9 1.9 55.7 546.5 2.8 2.9 68.7 637.6 4.0 4.6 81.1 728.1 6.1 7.5 87.8 819.0 9.3 11.7 89.7 913.4 13.6 17.3 90.6 1007.7 18.8 24.2 91.1 1102.0 24.9 32.0 91.1 1196.2 31.1 40.0 91.2 1290.5 37.0 47.7 91.3 1384.7 43.1 55.7 91.6 1479.0 49.0 63.8 92.0 1573.2 54.6 71.3 92.3 1667.6 59.5 78.0 92.5 1762.0 64.0 84.1 92.7 1856.3 68.3 90.0 92.8 1950.8 71.7 94.1 92.5 2045.4 73.9 96.0 92.0 2140.0 75.5 97.4 91.4 2234.5 77.2 98.8 90.8 HORIZONTAL COORDINATES feet 0.00 N 0.09 N 0.31 N 0.58 N 0.88 N 1.09 N 1.06 N 0.71 N 0.29 N 0.06 N 0.19 S 0.45 S 0.62 S 0.81 S 1.09 S 1.53 S 2.22 S 2.89 S 3.42 S 3.98 S 4.42 S 4.14 S 3.29 S 2.39 S 1.45 S 0.00 0.12 0.38 0.66 1.00 1.60 2.72 4.54 7.52 11.73 17.29 24.19 32.03 39.97 47.70 55.69 63.74 71.28 77.89 84.03 89.88 93.97 95.97 97.34 98.78 B.P. Exploration Well: NS-31, 5" DRILLPIPE Location: NABORS 33E, NORTHSTAR Job Number: AK505507SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 fl. A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 2273.3 0.92 61.87 0.18 2367.9 0.47 83.65 0.55 2462.5 0.42 85.64 0.05 2557.0 0.44 86.10 0.02 2651.6 0.41 87.92 0.03 2746.2 0.37 89.54 0.04 2840.8 0.35 91.29 0.02 2935.3 0.37 90.10 0.02 3029.9 0.29 97.76 0.10 3124.5 0.13 102.38 0.17 3219.1 0.15 91.39 0.04 3313.6 0.20 63.28 0.10 3408.2 0.19 51.84 0.04 3502.8 0.30 52.71 0.11 3597.4 0.37 51.17 0.08 3691.9 0.45 50.48 0.08 3786.5 0.47 54.47 0.04 3881.1 0.46 57.38 0.02 3975.7 0.47 57.97 0.01 4070.3 0.37 58.25 0.10 4164.8 0.38 62.98 0.03 4259.4 0.37 62.05 0.01 4354.0 0.27 85.30 0.18 4448.6 0.27 71.54 0.07 2329.1 78.8 100.2 90.4 2423.6 79.9 101.3 90.1 2518.2 80.5 102.0 90.1 2612.8 81.1 102.7 90.1 2707.4 81.7 103.4 90.0 2801.9 82.2 104.1 90.0 2896.5 82.7 104.7 90.0 2991.1 83.2 105.2 90.0 3085.7 83.6 105.8 90.0 3180.3 83.8 106.1 90.1 3274.8 84.0 106.4 90.1 3369.4 84.2 106.6 90.1 3464.0 84.5 106.9 90.0 3558.6 85.0 107.2 89.8 3653.1 85.5 107.7 89.6 3747.7 86.2 108.2 89.4 3842.3 86.9 108.8 89.2 3936.9 87.7 109.4 89.0 4031.4 88.5 110.1 88.8 4126.0 89.1 110.7 88.6 4220.6 89.8 111.2 88.4 4315.2 90.4 111.8 88.3 4409.7 90.9 112.3 88.2 4504.3 91.3 112.7 88.2 0.62 S 0.21 S 0.14 S 0.09 S 0.06 S 0.04 S 0.05 S 0.05 S 0.09 S 0.14 S 0.17 S 0.09 S 0.08 N 0.33 N 0.67 N 1.09 N 1.55 N 1.98 N 2.39 N 2.75 N 3.06 N 3.34 N 3.51 N 3.59 N 100.20 E 101.26 E 101.99 E 102.70 E 103.40 E 104.05 E 104.65 E 105.25 E 105.79 E 106.13 E 106.36 E 106.63 E 106.90 E 107.22 E 107.66 E 108.18 E 108.78 E 109.41 E 110.06 E 110.64 E 111.18 E 111.73 E 112.22 E 112.66 E B.P. Exploration Well: NS-31, 5" DRILLPIPE Location: NABORS 33E, NORTHSTAR Job Number: AK505507SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 4543.1 0.19 61.26 0.09 4637.7 0.19 62.13 0.00 4732.3 0.21 64.01 0.03 4826.9 0.22 65.24 0.01 4921.4 0.22 47.23 0.07 5016.0 0.15 41.66 0.08 5110.6 0.21 11.58 0.11 5205.2 0.23 18.61 0.04 5299.8 0.23 16.84 0.01 5394.3 0.21 323.99 0.21 5488.9 0.30 301.12 0.14 5583.5 0.27 299.15 5678.1 0.26 296.43 5772.6 0.27 291.28 5867.2 0.24 295.18 5961.8 0.25 292.61 6056.4 0.27 289.13 6150.9 0.28 287.17 6245.5 0.29 156.09 6340.1 0.25 287.91 6434.7 0.26 286.59 6529.3 0.29 285.01 6623.8 0.38 286.36 6718.4 0.39 290.34 0.03 0.02 0.03 0.04 0.02 0.02 0.02 0.55 0.52 0.02 0.03 0.09 0.03 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 4598.9 91.6 113.1 88.1 4693.5 91.9 113.3 88.0 4788.1 92.3 113.6 88.0 4882.6 92.6 114.0 87.9 4977.2 93.0 114.3 87.8 5071.8 93.3 114.5 87.7 5166.4 93.5 114.6 87.6 5260.9 93.8 114.7 87.4 5355.5 94.1 114.9 87.2 5450.1 94.3 114.8 87.1 5544.7 94.2 114.5 86.9 5639.2 94.0 114.1 86.8 5733.8 93.8 113.8 86.7 5828.4 93.6 113.4 86.6 5923.0 93.4 113.0 86.5 6017.6 93.2 112.6 86.4 6112.1 93.0 112.3 86.3 6206.7 92.7 111.8 86.2 6301.3 92.6 111.7 86.3 6395.9 92.4 111.6 86.4 6490.5 92.1 111.2 86.3 6585.0 91.9 110.8 86.2 6679.6 91.5 110.2 86.1 6774.2 91.2 109.7 86.0 HORIZONTAL COORDINATES feet 3.74 N 3.89 N 4.04 N 4.19 N 4.39 N 4.60 N 4.86 N 5.21 N 5.57 N 5.89 N 6.16 N 6.39 N 6.60 N 6.78 N 6.94 N 7.11 N 7.26 N 7.40 N 7.25 N 7.09 N 7.22 N 7.34 N 7.49 N 7.69 N 113.00 E 113.28 E 113.57 E 113.90 E 114.19 E 114.41 E 114.52 E 114.62 E 114.73 E 114.69 E 114.38 E 113.97 E 113.58 E 113.17 E 112.79 E 112.42 E 112.02 E 111.59 E 111.47 E 111.37 E 110.96 E 110.52 E 109.99 E 109.39 E B.P. Exploration Well: NS-31, 5" DRILLPIPE Location: NABORS 33E, NORTHSTAR Job Number: AK505507SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 fl. 6813.0 0.39 293.13 6907.6 0.48 299.64 7002.1 0.48 288.64 7096.7 0.52 301.59 7191.3 0.46 334.07 7285.8 0.46 347.20 7380.4 1.77 47.59 7474.9 3.49 54.50 7569.2 4.19 53.81 7663.5 5.44 46.25 7757.5 6.61 49.37 7851.3 8.37 51.65 0.02 0.11 0.10 0.12 0.29 0.11 1.68 1.84 0.74 1.48 1.29 1.88 7944.6 10.27 51.36 2.01 8037.3 12.50 49.68 2.39 8129.3 14.67 47.25 2.37 8220.3 16.97 48.98 2.49 8310.1 19.34 50.88 2.58 8398.8 21.40 49.81 2.21 8486.2 23.60 48.89 2.36 8572.4 24.81 48.28 1.31 8658.5 24.21 49.25 0.77 8745.0 23.52 49.34 0.73 8831.9 22.79 49.87 0.81 8919.2 22.58 49.88 0.22 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 6868.8 90.9 109.1 85.8 6963.3 90.5 108.5 85.6 7057.9 90.2 107.8 85.4 7152.5 89.8 107.1 85.2 7247.1 89.7 106.6 84.9 7341.6 90.0 106.4 84.5 7436.2 91.6 107.5 83.8 7530.6 95.9 111.2 82.7 7625.0 102.2 116.8 81.2 7719.3 110.1 123.6 79.3 7813.3 120.0 132.2 77.0 7907.1 132.4 143.4 74.8 8000.4 147.7 157.5 72.6 8093.1 166.3 175.0 70.3 8185.0 188.5 195.7 67.9 8276.1 214.2 220.2 65.6 8365.9 243.6 248.7 63.8 8454.6 276.5 280.8 62.2 8541.9 312.7 316.2 60.8 8628.2 351.4 354.2 59.4 8714.3 390.5 392.8 58.4 8800.7 428.8 430.6 57.6 8887.7 465.9 467.5 56.9 8975.0 502.4 503.7 56.4 HORIZONTAL COORDINATES feet 7.93 N 8.26 N 8.58 N 8.93 N 9.49 N 10.19 N 11.55 N 14.20 N 17.91N 23,04 N 29.69 N 37.51N 47.04 N 58.93 N 73.68N 90.87 N 109.82 N 130.83 N 154.41N 180.07 N 205.94 N 230.89 N 254.99 N 278.50 N 108.79 E 108.15 E 107.43 E 106.69 E 106.17 E 105.92 E 106.91E 110.33 E 115.46 E 121.48 E 128.85 E 138.38 E 150.36 E 164.75 E 181.35 E 200.56 E 223.13 E 248.46 E 275.90 E 304.99 E 334.50 E 363.50 E 391.82 E 419.71E B.P. Exploration Well: NS-31, 5" DRILLPIPE Location: NABORS 33E, NORTHSTAR Job Number: AK505507SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 fl. 9006.7 22.00 49.47 0.63 9094.7 21.01 49.39 1.05 9183.2 20.36 49.79 0.70 9361.0 19.55 49.14 0.44 9450.2 19.11 49.33 0.48 9539.9 17.97 49.37 1.20 9630.0 17.46 47.11 0.90 9720.3 16.91 46.95 0.59 9810.9 16.58 46.79 0.35 9901.7 15.96 47.03 0.66 9992.8 15.38 46.72 0.62 10084.1 14.93 46.47 0.49 10175.6 13.99 46.99 1.00 10267.5 13.24 47.51 0.80 10359.7 12.85 47.18 0.42 10439.8 12.31 46.07 0.72 10507.6 11.55 46.46 1.11 10601.4 10.81 48.09 0.84 10694.4 10.24 51.20 0.85 10788.1 10.12 50.03 0.25 10881.8 9.53 49.17 0.65 10975.7 9.32 48.03 0.29 11069.6 8.93 47.65 0.42 11163.6 8.36 47.39 0.59 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 9062.5 538.2 539.3 56.0 9150.5 572.8 573.8 55.6 9239.0 606.2 607.0 55.3 9416.7 670.7 671.3 54.7 9506.0 701.9 702.5 54.5 9595.7 732.0 732.4 54.3 9685.8 760.7 761.0 54.0 9776.1 788.5 788.8 53,8 9866.7 815.6 815.8 53.5 9957.5 842.0 842.2 53.3 10048.5 867.4 867.6 53.2 10139.8 892.0 892.1 53.0 10231.4 915.6 915.6 52.8 10323.3 937.7 937.8 52.7 10415.5 959.0 959.0 52.6 10495.6 976.8 976.8 52.4 10563.4 991.1 991.1 52.4 10657.2 1009.5 1009.5 52.3 10750.2 1026.8 1026.8 52.2 10843.8 1043.6 1043.6 52.2 10937.6 1059.8 1059.8 52.2 11031.4 1075.4 1075.4 52.1 11125.4 1090.4 1090.4 52.0 11219.4 1104.6 1104.7 52.0 HORIZONTAL COORDINATES feet 301.71N 324.25 N 345.90 N 387.85N 408.30 N 427.88 N 447.05 N 466.09 N 484.72N 502.83N 52O.29 N 537.28N 553.47 N 568.59 N 583.05 N 595.33 N 605.24 N 617.82N 629.02 N 639.69 N 650.21N 660.51N 670.63 N 680.29 N 447.07 E 473.40 E 498.83 E 547.90 E 571.61E 594.42 E 615.89 E 636.34 E 656.23 E 675.58 E 694.23 E 712.19 E 729.38 E 745.73 E 761.44 E 774.44 E 784.78 E 798.4O E 811.56 E 824.56 E 836.92 E 848.60 E 859.78 E 870.33 E B.P. Exploration Well: NS-31, 5" DRILLPIPE Location: NABORS 33E, NORTHSTAR Job Number: AK505507SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 11206.2 7.85 48.19 1.22 Final Station Closure: Distance: 1110.71 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 11262.0 1110.7 1110.7 52.0 Az: 51.96 deg. HORIZONTAL COORDINATES feet 684.36 N 874.82 E gyro/data 4. QUALITY CONTROL gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK505507 TOOL NUMBER: 682/813 MAXIMUM GYRO TEMPERATURE: 75.60 C MAXIMUM AMBIENT TEMPERATURE: 67.78 C MAXIMUM INCLINATION: 24.81 AVERAGE AZIMUTH: 5.73 WlRELINE REZERO VALUE: REZERO ERROR / K: CALIBRATION USED FOR FIELD SURVEY: 4O83 CALIBRATION USED FOR FINAL SURVEY: 4O83 PRE JOB MASS BALANCE OFFSET CHECK: POST JOB MASS BALANCE OFFSET CHECK] · -.82 -.65 CONDITION OF SHOCK WATCHES UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY FINAL SURVEY 11421 7.85 48.19 11262.0 684.4N 874.8E gyr( data FUNCTION TEST JOB NUMBER: AK505507 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 11380 8.37 8.37 8.37 8.37 8.37 AZIMUTH M.D. fl 1 2 3 4 5 11380 47.22 47.22 47.22 47.29 47.29 gym/data CHRONOLOGICAL REPORT JOB NUMBER' AK505507 SUNDAY, 05/20/01 00:00 FINISH JOB 506 15:00 PU AND CHECK 1.8" TOOLS MONDAY, 05/21/01 14:00 16:00 TO WEST DOCK ARRIVE NORTHSTAR, READY A.M. 19:00 MU TOOL ON RIG FLOOR, STANDBY TUESDAY, 05/22/01 00:15 DROP TOOL, PUMP 2000 STROKES @ 40SPM 01:30 09:30 11:00 22:00 TOOL DOWN, START TOOH RETRIEVE TOOL, LD TOOL, BD TOOL DOWNLOAD DATA PROCESS SURVEY WEDNESDAY, 05/23/01 10:00 12:00 17:30 TO WEST DOCK TO DEADHORSE, JOB AT MILNE FRIDAY TO ANCHORAGE gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT gyro/data EQUIPMENT REPORT JOB NUMBER: AK505507 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 813 GYRO SECTION A0162 DATA SECTION C0211 POWER SECTION C0207 COMPUTER POWER SUPPLY PRINTER INTERFACE A0693 A0107 A0029 A0166 BACKUP TOOL No. 682 GYRO SECTION A0206 DATA SECTION C0159 POWER SECTION C0197 COMPUTER POWER SUPPLY PRINTER INTERFACE A0527 A0085 A0165 RUNNING GEAR TOTAL LENGTH OF TOOL: 27' MAXIMUM O.D.: TOTAL WEIGHT OF TOOL: 175 IL sper r, -sun [~ F~ I I...1... I I~1 I::S SE~UIC:ES BP EXPLORATION ALASKA END OF WELL REPORT NORTHSTAR NS-31 . 1 . . . . 1 . . 11, TABLE OF CONTENTS General Information Daily Summary Daily Operations Show Reports Morning Reports BHA's Bit Record Mud Reports Survey Record Formation Tops Formation Evaluation Logs GENERAL WELL INFORMATION Company: Rig: Well: Field: Borough: State: Country: APl Number: Sperry-Sun Job Number: Job Start Date: Job End Date: North Reference: Declination: Dip Angle: Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates N: Wellhead Coordinates W: Vertical Section Azimuth: SDL Engineers: Company Representatives: Company Geologist: Lease Name: SSDS Unit Number: State: Borough: BP Exploration Alaska Nabors Alaska Drilling No. 33-E Northstar NS-31 Northstar North Slope Alaska United States 50-029-23009-00 AKAM10142 April 26, 2001 May 22, 2001 True 26.817 deg 80.919 deg 57502.155 nT May 17, 2001 North 70 deg 29 min 31.189 sec East 148 deg 41 min 34.776 sec 52.230 deg Doug Wilson Mark Lindloff Tom Mansfield Wayne Hermanson Paul Lockwood Steve Christian Joe Polya Mike Dinger Ken Lemley Northstar 40O87 Alaska North Slope BP Exploration - Northstar NS$1 Daily Summary 04-26-01 - Moved Rig to NS-31. It was discovered that the Rig was offcenter by 2" west. Skidded rig floor 2" to accommodate misalignment. Nippled up riser and diverter..Made up BHA# I and drilled out ice plug. Spudded from 199' to 23 l'. Prepare to run Gyro survey. 04-27-01 - Run Gyro survey at 20" shoe. Picked up directional BHA #2. Drilled 16" hole from 23 l' to 315' where the drag chain fbr cuttings transport to G&I broke. When repaired continued drilling from 23 I' to 463" where the hole was kicked off (nudgged) from 463' to 1163' periodically running gyros. Hole angle was increased over the interval from 0° to 5°. 04-28-01 -Continued drilling fi.om 1163' to 1900' reducing hole angle back to near vertical. Drilled fi.om 1900' to 2474' where well started taking fluid. High Vis and Barafiber sweeps were pumped. Drilling continued and mud losses were virtually stopped by the time casing point was reached at 3249'. Circulated hole clean. 04-29-01 - Started pulling out of the hole with tight spots at -1100' pulled up to 887' and wiped back to 1390' three times - no over pull on last pass through tight spot. Laid down BHA# 2. Picked up and ran 13 3/8" casing to 3237'. Started preparing for cementing. 04-30-01 - Circulated casing at I0 bbls/min with no losses. Cemented first stage according to well plan. Waited 5.5 hrs and ran second stage cement job to surface. Nippled down diverter and started nippling up BOP. 05-01-01 - Finished nippling up BOP's. Tested BOP's as per BP policy. Made up BHA #3 and ran in hole to ES Cementer at 1605'. Tested casing to 1000 psi and drilled ES Cementer. Casing was again tested to 1000 psi. Ran in the hole to 2900' and washed to Baffle Adapter at 3150'. Casing was tested to 2500 psi in preparation for drilling out the cement and shoe. 05-02-01 - Drilled out float track, rathole and 20' of new hole to 3269'. Circulated and conditioned mud and performed a formation leak-offtest to an equivalent mud weight of 15.3 ppg. The hole was displaced with new KCL/Polymer mud. Drilling continued from 3269' to 4785'. 05-03-01 - Drilled 12 IA" hole from 4785' to 5350'. Wiper trip to shoe. Hole was ti~t on the trip out and started swabbing on 13 stand. Back reamed from approximately 4190' to shoe. Slipped and cut drilling line. Ran back to bottom with no problems. Drilled 12 IA" hole from 5350' to 5732'. Trip gas from wiper trip peaked at 1458 units. The higher than normal peak was probably due to swabbing while wiping out. 05-04-01 - Drilled 12 '/4" hole from from 5732' to 6959'. Passed through the Schrader Bluffat 6400'. Due to the slow rate of penetration at the top of the Colville shales the bit was pulled. Prior to the trip a sweep was pumped. 05-05-01 - Circulated - added Torque-Trim 2 in preparation for sliding with a PDC bit. Pulled two stands - swabbing. Worked tight hole and back reamed from 6780' to 3650'. Tripped out of hole and tested BOP's. Start to make up BHA. 05-06-01 - Could not run 1.5° mud motor bent housing through the wear bushing. Finally had to make up bit and motor, then slip wear ring over stump in slips. When slips were pulled the wear ring was allowed to fall into place and was locked down. Made up BHA and attempted to sallow test MWD. Caused violent reactive torque because of bent housing, therefore abandoned test and ran into open hole to test MWD. Ran in to 6887' and precautionary reamed last stand to bottom. Pumped a 20 bbl walnut hull sweep for ant-bit bailing. Drilled 12 '/4" hole from 6959' to 7072' where MWD signal tailed. Drilled stand down, circulated sweep and pulled out 2 stand. Decided to abandon trip out and ran back to bottom. Drilled from 7072' to 7358' and circulated bottoms up. Pulled out of hole to replace MWD/LWD tools. 05-07-01 - Completed trip out. Unloaded ADN source and replaced defective tools. Had to pull wear ring and replace as described above. Ran in hole to 3295' and shallow tested MWD. CDR tool was not communicating, but decided to run to bottom anxxvav. Ran in to 7171' and shot a survey. Precautionarv reamed fi.om 717 I' to bottom. Directional drilled from 7358' to 7830' kicking hole offsloxvlx. Note: CDR tool began to communicate intermittentlx starting at 7374'. 05-08-01 - Directional drilled 12 ' ~" hole from 7830' to 85,7,0'. Note: A lot of bit bouncing when rotating. 05-09-0l - Directional drilled 12 ' ~" hole from 8570' to 9116' (bit still bouncing). Circulated high gas fi.om Kuparuk C sand. Gas peaked at 8404 units, cutting mud weight from 9.8 to 8.7 ppg. After gas circulated out, repaired pump =1 while circulating BP Exploration - Northstar NS31 Daily Summary with pump ~-2. Directional drilled from 9116' to 9158' where drilling was suspended to circulate gas. Maximum gas was 6573 units, cutting mud weight from 9.8 to 8.8 ppg. Drilled 12 ',q" hole fi.om 9158 to 9330'. 05-10-01 Drill from 9330 to 9438'. Spot Steel Seal pill across Schrader Bluff'. Short Trip to 7265'. with short trip gas of 320 units. Wei~,ht Mud up to I I 3 ppg. Drill fi.om 9438 to 991 '~' 05-11-01 Drill 9912' to 10406'. Pull one stand and replace swabs and liners on pump #2. Pull one stand to 10265' recipricate and circulate backreaming with one pump. Pull one stand to 10177'. recipricate and backrearning. Change out liners on pump # 1. Backream to 9347'. Run in hole. Drill from 10406' to 10612'. ROP decreased from 70 ft/hr average to 18 f-t/hr ( possible bit bailing ). Pump 2 nut plug sweeps. Drill from 10612 to 10618'. 05-12-01 Drill 10618 to 10826'. Work on pumps. Drill 10826 to 10945, T>D> for intermediate casing. Circulate out. Short Trip to 8590'. Trip in to bottom and CBU ( Short trip gas 164 units ). Prepare to spot Steel Seal pill across Schrader Bluff. 05-13-01 Spot Steel Seal pill across Schrader Bluffand TOH. Lay down bottom hole assembly. Rig up to run 9 5/8" (53.5 lb/f0 casing. Run 9 5/8" casing. 05-14-01 Run 9 5/8" casing to approximately 35' from bottom-noted displaced returns until pick up casing hanger and landing joint. Worked pipe in an attempt to circulate: casing packed off. Rig down casing tools and pickup cement head and work pipe ( staging pressure fi.om 500 psi to 3000 psi ) -no circulation-gradually worked pipe until casing landed. Rig up wireline to find packoff point. 05-15-01 Run wireline logs, rig down and elevate usit and prepare for running perforation guns. Pickup perforation guns and run in hole ( fired guns at approximately 10" above gloat collar ) 05-16-01 Rig up cement head and circulate with maximum gas of 1200 units. Pump cement down hole and displace mud taking returns via drag-chain to G & I unit ( approx. 6 hours ). Clean L-pit, 1 & 2 and trip tank while wait on cement. 05-17-01 Wait on cement. Set emergency casing slips, clean pits and mud up Dril-n0fluid. Trip in hole with Drill pipe to tag top of cement. 05-18-01 Trip in hole to 10,000',. Test choke manifold. Laydown drillpipe. Drain BOP stack. Pull wear ring. Perform freeze protection between 9 5?8" and 13 3/8" casing using 108 bbls diesel and 4 bbls escaid. Make uptest plug. Test BOP's. 05-19-01 Finish testing BOP's. Pickup 5" drill pipe and new 8 1/2" bit without MWD. Trip in hole todrill cement. Tag cement at 10486'. Begin drilling cement. 05-20-01 Drill out cement and 20' of new hole to 10965' MD. Perform Formation Integrity Test with 10.2 ppg mud (Static -no added pressure). Circulate and clean hole. Clean L pits and pit !. Monitor hole. Displace old KCL Polymer ( 10.2 ppg ) with 9.3 ppg Drill-N-Fluid. Drill ahead from 10965' MD. At 11079' MD observe maximum gas of 895 units with a mud cut from 9.2 to 8.8+ ppg. 05-21-01 Drill to T>D> of 11440' MD. Monitored well-OK. Wiper trip to 9 5/8" casing shoe. Monitored well-OK. Trip in hole to bottoTM and circulated bottoms up with a short trip gas of 141 units. Continued circulating additional % bottoms up. Trip out of hole for wireline logs. 05-22-01 Trip out of hole. Run Electric logs. Time BP Exploration - Northstar NS-31 Daily Operations (I.A.D.C.) Elapsed Code Operations Breakdown (hrs) Time 04-25-2001 1600-1700 1.00 1700-1930 2.50 1930-2030 1.00 2030-2230 2.00 2230-2330 1.00 2330-2400 0.50 04/26/2001 0000-0300 3.00 0300-0330 0.50 0330-0500 1.50 0500-0630 1.50 0630-1000 3.50 1000-1130 1.50 1130-1200 0.50 1200-1300 1.00 1300-1330 0.50 1330-1430 1.00 1430-1500 0.50 1500-1700 2.00 1700-2030 3.50 2030-2100 1.50 2100-2130 0.50 2130-2230 1.00 2230-2300 0.50 2300-2400 1.00 04127/2001 0000-0100 1.00 0100-0230 1.50 0230-0600 3.50 0600-0700 1.00 0700-1000 3.00 1000-1130 1.50 1130-1300 1.50 1300-1330 0.50 1330-1430 1.00 1430-1600 1.50 1600-1700 1.00 1700-1730 0.50 1730-1830 1.00 1830-1930 1.00 1930-2030 1.00 2030-2400 3.50 04/28/2001 0000-0130 1.50 0130-1200 10.50 1200-1500 3.00 1500-1530 0.50 1530-2200 6.50 2200-2400 2.00 04/29/2001 0000-0100 1.00 0100-0300 2.00 0300-0400 1.00 0400-0430 0.50 0430-0730 3.00 I Prepare rig for move. Release rig from NS 29 at 16:00 hrs on April 26, 2001. I PJSM & unplug 1380v cable. I Move rig from NS-29 to NS-31. 21 PJSM. Chink cellar & set BOP back & secure. Free up bridge crane to install riser sections. 14 Set lower Riser section. I Install mouse hole & prepare upper riser section. 14 Nipple up upper section of scoping riser. Realize that upper & lower section of riser were misaligned & unable to seal upper flange & lower clamp assembly. Rig off center - must realign rig. 14 Pull upper section of riser. 1 Inspected rig floor for skidding capacity versus modifications & possible damage - determined no risk of damage. PJSM to prepare procedure & perform hazardous risk assessment for skidding rig floor. 1 Loosen 9 bolts removing 2. Skidded rig floor 3" to east. Tighten 7 bolts. 14 Re-install upper section of scoping riser. Nippled up & connected flowline. 14 Pick up 13 3/8" mandrel landing hanger & 13 3/8" landing joint. Drift diverter & land hanger in landing ring. Confirm measurement 45.15' RKB. 21 POOH with 13 3/8" mandrel landing hanger. Caught hanger on bottom end of upper riser section & curled lip. Finish POOH with landing joint & mandrel hanger. 21 Pull riser for repair. 15 Perform diverter test. 14 Re-install upper riser section & re-connect flowline. 14 Re-drift stack with 13 3/8" mandrel casing hanger. 7 Perform electrical preventative maintenance on top drive. $ Make up BHA. Change out jars & pick up 3 joints of HWDP. 21 Flow test shakers at 800 gpm - OK. 21 Clean out ice in 20" conductor from 55' to 134'. 6 Blow down, stand back 1 stand of HWDP & make up remainder of clean out BHA. 2 Continue cleaning out 20" conductor from 134' to 199'. Spud While drilling from 199' to 231'. 5 Circulate hole clean. PJSM for rigging up wireline for gyro. 20 PJSM. Run Gyro survey at 20" conductor shoe. Inclination 0.4° & azimuth of 22.3°. 6 Lay down rotary clean out BHA. 6 Pick up directional BHA. Orient MWD & mud motor. RIH to 231'. 2 Drill 16.00" hole from 231' to 315'. Shaker cuttings discharge drag chain link broke in 2 places. Circulate hole clean. 8 Repair drag chain. Chain links were severely worn on outward side. 2 Drill 16.00" hole from 2315' to 463'. 20 Circulate hole clean while holding PJSM. Run Gyro survey (incl 0.7°, az 88.5°) 2 Directional drill 16.00" hole from 460' to 555'. 5 Circulate hole clean while holding PJSM regarding Gyro survey. 2 Directional drill 16" hole from 655' to 646'. .5 Pump sweep & circulate hole clean while holding PJSM regarding Gyro survey. 2 Directional drill 16.00" hole from 646' to 736'. $ Pump sweep & circulate hole clean while holding PJSM regarding Gyro survey. 2 Directional drill 16.00" hole from 736' to 828'. 5 Pump sweep & circulate hole clean while holding PJSM regarding Gyro survey. 2 Directional drill 16.00" hole from 828' to 1194' 5 Pump sweep & circulate hole clean while holding PJSM regarding Gyro survey. Run gyro survey to of 5.03° & 90.71° azimuth to confirm MWD survey of 5.21° inclination & 91.16° azimuth. 2 Drill 16.00" hole from 1194' to 2330'. 2 Drill 16.00" hole from 2330' to 2613' - lost 75 bbls mud while drilling at 2474'. Shut down pumps & observe well during connection. Losing ~ 1 bbl/min while drilling (710 gpm). 5 Pump Hi Vis sweep with Barafibre while pumping surface to surface at 710 gpm. 2 Drill 16.00" hole from 2613' to 3249'. Note: added 130 sks Barafibre while drilling & losses reduced to 0 by TD. 5 Circulate & condition mud while reducing YP from 30 to 27 5 Circulate & condition mud. Observe well - static. 6 POOH to run 13 3~8" casing (no wiper trip prior to cementing because only tight spot was thru top of perafrost section, which was wiped thru until pipe went thru with no overpull). 6 POOH from 887' to 190' - max overpull 5-10k. 6 PJSM on laying down BHA. 6 Lay down directional BHA. Stabilizers were packed with large amounts of clay that was easily removed. BP Exploration - Northstar NS-31 Dally Operations (I.A.D.C.) Time (hfs) Elapsed Code Operations Breakdown Time 0730-0800 0800-0900 0900-1100 1100-1200 1200-1300 1300-1930 1930-2030 2030-2100 2100-2130 2130-2200 2200-2230 2230-2400 04130/2001 0000-0130 0130-0300 0300-0330 0330-0830 0830-1100 1100-1200 1200-1300 1300-1400 1400-1500 1500-1830 1830-2130 2130-2400 05/0112001 0000-0400 0400-0430 0430-1130 1130-1200 1200-1300 1300-1330 1330-1400 1400-1430 1430-1530 1530-1600 1600-1700 1700-2100 2100-2300 2300-2400 05/02/2001 0000-0030 0030-0300 0300-0330 O33O-O4OO 0400-0500 0500-0600 0600-1200 1200-2400 0.50 1.00 2.00 1.00 1.00 6.50 1.00 0.50 0.50 0.50 0.50 1.50 1.50 1.50 0.50 5.00 2.50 1.00 1.00 1.00 1.00 3.50 3.00 2.50 4.00 0.50 7.00 0.50 1.00 0.50 0.50 0.50 1.00 0.50 1.00 4.00 2.00 1.00 0.50 2.50 0.50 0.50 1.00 1.00 1.00 12.00 21 Clean up rig floor of tools & assesories. 21 While cleaning clay balls off stabilizers a large chunk of clay dropped on hole cover rubber mat & it caused the mat to fall down hole. Attempts to retieve the mat were unsuccessful. 21 PJSM. Rig up casing running equipment. Drain stack & inspect for rubber mat - did not locate it. 12 PJSM for running casing. Make up float track. Baker lock to pin end on joint #3. 12 Rig up frank's tool. Engage the element & circulate thru float equipment - good test. 12 RIH with 76 joints 13 3/8" 68# L80, BTC. 12 Work thru tight spot with joint #77 at 3087' - whuch correlated to the SV6 clay formation. Attempt to engage the Frank's tool & circulate - Frank's tool plugged. Rig down frank's tool. 12 Finish running last 2 joints of casing, #78 & #79. 12 Make up mandrel casing hanger. 12 Make up landing joint & land casing hanger. 12 Rig up crossover & cementing head. 12 Gradually increase circulation at 0.5 bbls per 10 min until 3 bbls/min. Increase rate by 1 bbls per 10 rain until 10 bbls/min attained, Did not reciprocate pipe because of rubber mat problem & concerns about scraping off LCM across loss zone. 12 Continue to circulate in preparation to pump 1st stage cement job. 12 Pump Ist stage cement job. Drop bottom plug, Test lines to 3500 psi. Load plug. Mix & pump 75 bbls Alpha spacer, 95 bbls (470 sks) Perafrost "E" cement & 96 bbls (470 sks) Premium "G" cement. Displace with rig pumps & bump plug with 483 bbls & 1000 psi. 12 Bleed pressure & check floats - OK. Preparation for stage 2. Load Closing Plug for ES Cementer in cement head. Pressure up & open ES Cementer at 2300 psi pumping at 3.0 bbls/min. 12 Circulate thru ES Cementer at 10,0 bbls/min. PJSM for stage 2 cement job. 12 Mix & pump 2nd stage cement job as follows: 75 bbls Alpha spacer, 411 bbls (1064 sks) Permafrost "E" cement. Continued to pump cement until cement returns witnessed at surface. Dipsplaced with rig pump & bump closing plug with 240 bbls of thick clabbored cement returns to surface -120 bbls into displacemet. Increased pressure & closed ES Cementer with -1400 psi, which increased to 1900 psi. Pressure held to ensure no leaks. Release pressure & check for back flow - none detected. 12 Rig down cement head & elevators. Pull landing joint. Flush & drain stack. Blow down cement & mud lines. 12 Lay down landing joint & change out bails. 12 Rig up jetting tool (perorated pipe) & flush cement out of hanger, diverter bag & mud pumps. 13 Blow down all lines & clean rig flloor. 14 Nipple down riser & diverter, 14 Clean cellarm & make up speed head. 14 PJSM & nipple up BOP's. 14 PJSM & nipple up BOP's. 15 PJSM for testing BOP's. 15 Make up test plug & fill stack. Test BOP's & choke manifold as per BP policy. Pull test plug. Run wear bushing. Blow down choke & kill lines. 6 PJSM for making up BHA #3. 6 Make up BHA. 20 Orient MWD. 6 Make up BHA. 6 RIH with HWDP. 20 Shallow test MWD. 6 PJSM for drifting DP while RIH from derrick. 21 Drift stuck in frost in tool joint. Start to lay down stand & drift. Dropped to bottom of stand. Decided to dcancel plan to drift DP. 21 Tag ES cementer at 1605'. Test casing to 1000 psi. Drill ES Cementer. Test casing to 1000 psi for 5 min. Blow down lines. 6 RIH to 2900'. Wash to Baffle Adaptor at 3150', 15 Test casing to 2500 psi for 30 min. 15 PJSM & test 13 3/8" casing. 21 Drill out float track, rat hole & 20' of new hole to 3269'. 5 Circulate for LOT until mud weight in equals mud weight out. 21 Perform LOT to 15.3 ppg MWE. 5 Displace well with new KCLJPolymer drilling fluid. Note: suggestion in PJSM to empty L pit into the G&I thru the mud header line instead of the trpogh. This was successful & allowed the displacement rate to be increased from 8 bbls/min to 16 bbls/min, while also eliminating spill potential. 21 Shut down to clean old mud out of L pit & lA suction pit. 2 Drill 12 '/," hole from 3269' to 3695'. 2 Drill 12 ¼" hole from 3695' to 4785'. Time BP Exploration - Northstar NS-31 Daily Operations (I.A.D.C.) Elapsed Code Operations Breakdown (hrs) Time 05/03/2001 0000-0630 6.50 0630-0800 1.50 0800.1000 2.00 1000-1130 1.50 1130-1230 1.00 1230-1300 0.50 1300-1530 2.5 1530-1600 0.50 1600-1700 1.00 1700-1800 1.00 1800-2400 6.00 05/04/2001 1100-1200 12.00 1200-2330 11.50 2330-2400 0.50 05/05/2001 0000-0130 1.50 0130-0200 0.50 0200-0500 3.00 0500-0800 3.00 0800-0900 1.00 0900-1030 1.50 1030-1430 4.00 1430-1530 1.00 1530-2000 4.50 2000-2030 0.50 2030-2130 1.00 2130-2200 0.50 2200-2400 2.00 05106/2001 0000-0100 1.00 0100-0300 2.00 0300-0400 1.00 0400-0430 0.50 0430-0530 1.00 0530-0700 1.50 0700-0730 0.50 0730-0900 1.50 0900-0930 0.50 0930-1200 2.50 1200-1400 2.00 1400-1930 5.50 1930-2100 1.50 2100-2400 3.00 05/07/2001 2 Drill 12 '/," hole from 4785' to 5350'. 5 Circulate around fibre sweep. Shut down pumps & monitor well - static. Ump Dry Job. 6 Wiper trip 13 stands to 4691' - swabbing on stand 13. 3 Back ream stands 14 to 23 back into 13 3/8" casing shoe. 7 Blow down top drive & mud lines. Clean rig floor. PJSM for slipping & cuffing line. 21 Safety time out. Circulate on trip tank to keep hole full. Discussed individual safety & safety of those working around you. 9 Slip & cut 102' of drilling line. 7 Adjust brakes. 7 Service top drive & crown. 6 Wiper trip in hole to 5350' - no problems. 2 Drill 12 %" hole from 5350' to 5732'. 2 Drill 12 %" hole from 5732' to 6413'. 2 Drill 12 '/4" hole from 6413' to 6959'. 5 Pump sweep. Circulate & condition mud while sweeping hole. 5 Circulate & condition mud for bit trip. Added Torque trim 2 in preparation for sliding with PDC bit. 6 Check for flow - static. POOH 2 tads to 6780'. 3 Work tight hole from 6780' to 5543' - swabbing on last stand. 3 Back ream from 5543' to 3650' at 750 gpm, 1350 psi & 60 rpm. Attempted to pump out of hole but overpull requires back reaming. 6 POOH from 3650' to 3188', into 13 318" shoe - no excess overpull. Check flow & pump Dry Job. 6 POOH to BHA. 6 PJSM & lay down BHA. No clay on stabilizers, motor or bit. Bit grading 6-5.WT-A-E-1116-ER-ROP. 15 PJSM. Rig up BOP test tools. Pull wear ring & run test plug. 15 Test BOP's 250 / 5000 psi as per BP policy. 15 Rig down test tools. Pull test plug & run wear ring. 7 Service top drive, travelling blocks & crown. 21 Finish cleaning & inspecting cellar. Note: bubbles observed in cellar. Determined to be oxygen not gas. Stopped after 20 min. No subsequent bubbles observed. 6 PJSM & make up BHA. 21 Unable to RIH with bit & 1.5° mud motor past wear bushing. Retieved wear ring - no sign of damage. Finally decided to make up PDC, RIH & set MWD in slips. Slipped wear ring over stump. Made up DC's, pulled slips & allowed wear ring to drop into place. Ran Iockdowns. 6 PJSM. Made up BHA & dropped wear ring into place as described above. Verify wear ring fully seated by checking tick mark through backed out lock down port - ran in 4 lock down screws in N - E - W - -S orientation. 6 Make up BHA. 20 Attempt to perform surface test of MWD - due to 1.5° bent sub violent reactive torque while bringing pumps up to 30 spm. Suspend test until assembly below casing shoe. 21 PJSM. Pick up ADN tool. (Clear floor & load tool.) 6 RIH to 3295' to position bit & motor below surface casing shoe. 20 Shallow test MWD at 740 gpm 1300 psi. Established ECD baseline while rotating at 50 rpm. 6 RIH from 3295' to 6887' - no problems. 3 Precautionary ream from 6887' to 6955' at 50 rpm, 800 gpm & 1900 psi. Pumped 20 bbl walnut hull sweep & circulated with bit just above bottom as an anti-bit bailing measure. 2 Drill 12 ¼" hole from 6959' to 7072'. MWD signal failed. Finished drilling down stand. Note: Bit showed no signs 'of bailing. When differntial on motor increased above 350 psi the bit bounced, corresponding to fluctuations in pump pressure. 6 Circulate a sweep. Pull 2 stands with no problems. Pump Dry Job in preparation for trip to replace failed MWD. Decision was made to go back to bottom & drill to kick-off point at -7500'. Decision based on the fact that the hole was not deviated at the time & State regulations only require a survey every 500' in that case. This would be a good chance to evaluate performance of this PDC bit. The MWD tool may have started working in the mean time. 2 Drill 12 ¼" hole from 7072' to 7358'. Bit bounce resulted from increased differential across mud motor. Tried different flow rates, etc. - conclusion: probably due to drilling straight hole with no shock sub, when drilling deviated hole pipe laying on side of hole absorbs shock. 5 Circulate bottoms up. 6 POOH to replace MWD/LWD equipment. BP Exploration - Northstar NS-31 Daily Operations (I.A.D.C.) Time (hfs) 0000-0100 0100-0200 Elapsed Code Time 1.00 Operations Breakdown 6 POOH to BHA- at ADN tool. 0200-0300 0300-0430 0430-0500 0500-0630 0630-0800 0800-0830 0830-1000 1000-1100 1100-1200 1200-2400 05/08/2001 0000-1200 1200-2400 0510912001 0000-1400 1400-1630 1630-1700 1700-1800 1800-1830 1830-2400 05110/2001 0000-0230 0230-0430 0430-0730 0730-1330 1330-2300 2300-0000 0511112001 0000-0800 0800-0830 0830-0930 0930-1800 1800-1830 1830-1930 1930-2030 2030-0000 05/12/2001 0000-0900 0900-0930 0930-1830 1830-2030 2030-2300 2300-0000 1.00 21 1.00 1.50 0.50 1.50 1.50 0.50 1.50 1.00 1.00 12.00 12.00 12.00 14.00 2.50 0.50 1.00 0.50 5.50 2.5 2.0 3.0 6.00 9.50 1.00 8.00 0.50 1.00 8.50 0.50 1.00 1.00 3.50 9.00 0.50 9.00 2.00 2.50 1.00 PJSM. Clean floor while Anadrill unloads ADN source. 6 POOH with BHA from 280' to 100'. Dowtoad Isonic at rig floor. 21 Change out MWD tool. Orient new tool with mud motor. Inspect bit- OK. 21 Pull wear ring. 6 RIH with BHA. Note: wear ring dropped into place from rig floor as discussed on previous trip. 6 RIH from 300 to 3295' &. 21 Shallow test MWD & establish ECD baseline. CDR tool not communicating - decision to continue RIH. PWD & GPJRES are affected, but MWD has GR. 6 RIH from 3295' to 7100'. 3 Fill DP. Shoot survey at 7171'. Precautionary ream from 7171 to 7358' while pumping 20 Ibs/bbl wallnut hull for ant-bit bailing. 2 Directional drill 12 ¼" hole from 7358' to 7374' to begin kick-off. CDR tool began to communicate with MWD. 2 Directional drill 12 ¼" hole from 7374' to 7830'. CDR tool intermittently communicating with MWD. 2 Directional drill 12 ¼" hole from 7830' to 8231'. Bit bouncing when rotating. 2 Directional drill 12 %" hole from 8231' to 8570'. Bit bouncing when rotating. 2 Directional drill 12 1/4" hole from 8570' to 9116'. Bit bouncing when rotating. 5 Circulate out gas. Max gas 8404 units from Kuparuk C sand - mud cut from 9.8 to 8.7 ppg. 8 Continue circulating with pump #2 while repairing pump #1 pulsation dampner crossover swedge. 2 Directional drill 12 ¼" hole from 9116' to 9158'. Bit bouncing stopped. 5 Circulate out gas. Max gas 6573 units - mud cut from 9.8 to 8.8 ppg. 2 Directional drill 12 ¼" hole from 9158' to 9330'. Drill/Slide from 9330' to 9438'. No drill string bounce. Running 95 SPM and 120 SPM on mud pumps. Maintain 400-500 psi motor differential. ROP-50 fph. Circulate Bottoms up. Spot 70 bbls Steel Seal pill across the Schrader Bluff formation. Wiper trip from 9438' to 7265'. Hole Slick, no problems. Rotate and reciprocate pipe while weighting up mud system from 9.8 to 11.3 ppg for Kingak drilling. Drill/Slide from 9438' to 9911'. No drill string bounce, running 95 spm and 120 spm on mud pumps. Maintain 400-500 psi motor differential. ROP~40-80 fph. Change swab in #2 mud pump Drill from 9911' to 10327'. No drill string bounce. Change out swab in mud pump #1 Drill from 10372' to 10406'. Change out swab in #2 mud pump. This was the same liner that a swab had been changed out at 2300 hrs the previous night. Decision made to change out all swabs and liners in both pumps. Mud pump #1had - 690 hrs. on the liners, and mud pump #2 -650 hrs. on the liners. All liners showing definite wear. Continue to circulate with 1 pump at a time and rack back a stand every 30 minutes. GIH back to bottom to start drilling after mud pump repairs. Drill from 10406' to 10448'. Flange on #1 mud pump high pressure discharge line started leaking. Tighten flange bolts. Stop leak. Drill from 10448' to 10636'. At 10612' ROP went from~75 fph to 16 fph. P/U off bottom and pump 2-20 bbls/151bs/bbl nut plug sweeps. Vary WOB, Rotary, and SPM. ROP consistant at 15-20 fph. No change in formation samples. Discuss with Geologist. Continue to drill ahead to get Gamma ray across the 10612' section. Drill ahead to 1636". No drill string bounce. ROP -20 fph. Pump 3rd 20 bbls 15 lb nut plug sweep. No change in ROP. Cont to drill ahead. Re-charge #2 mud pump pulsation dampner to 650 psi. Drill ahead to final hole section TD. Geology picked the top of the Sag River at 10867' MD, 10715' TVD. ROP increased to 20 to 37 fph. Max gas 1208 units. Geology picked final hole TD at 10945' MD 10791" 'I'VD. Circulate bottoms up for sample and wiper trip. Bottoms up sample showed silty sandstone indicating Sag River formation. Wiper trip 24 stands up through the top of the HRZ. Max pull through the Kingak was 25k over. Rest of the trip was slick, No problems. GIH to TD. Hole Slick, No problems. Time BP Exploration - Northstar NS-31 Daily Operations (I.A.D.C.) Elapsed Code Operations Breakdown (hfs) Time 05/13/01 0000-0230 2.50 0230-0400 1.50 0400-0900 5.00 0900-1030 1.50 1030-1130 1.00 1130-1300 1.50 1300-1500 2.00 1500-2030 5.50 2030-2200 1.50 2200-0000 2.00 05/14/01 0000-0100 1.00 0100-0330 2.50 0330-0530 2.00 0530-0800 2.50 0800-0900 1.00 0900-2030 11.50 2030-2130 1.00 2130-2300 1.50 2300-0000 1.00 05115101 0000-0100 1.00 0100-0430 3.50 0430-0830 4.00 0830-1030 2.00 1030.1700 6.50 1700-2030 3.50 2030.2130 1.00 2130-2330 2.00 2330-0000 05/16/01 0.50 0000-0030 0.50 0030-0300 2.50 0300-0430 1.5 0430-1300 8.5 Circulate out after wiper trip at TD, and condition mud for running casing. Trip gas 164 units. Spot 75 bbls Steel Seal LCM pill across the Schrader Bluff formation, and pump down Sperry Sun 1.8" gyro. Pump slug. Blow down top drive. POOH to 13 3~8" casing shoe. Hole slick. No problems. Slip / cut drill line. Service top drive, blocks,and crown. POOH to last stand of drill pipe. Change top rams from drill pipe VBR's to 9 5~8" casing rams. pooh to ADN. Unload source. Continue POOH to BHA and LID same. No bailing on stabilizers. Bit balled up. Three junk slots and corresponding nozzles plugged up. Significant wear on bit curers. Pull wear bushing. Set test plug and test 9 5~8" casing ram doors to 1000 psi. flU 9 5/8" casing tools. Finish R/U casing tools and hold PJSM for running casing. Bakerlok bottom three joints of casing. Break circulation to ensure floats are open. Continue running 9 5/8", 53.50#, L-80, BTCM casing. Part electrical wire for stabbing board while moving the stabbing board down. Replace electrical wiring and secure same. Continue running a total of 75 jts 9 5/8" casing to 3100' ( 13 3/8" shoe at 3237' ). Circulate bottoms up at the 13 3/8" shoe. Maintain full returns. Continue running 9 5/8" casing. Run a total of 266 jts. Hole slick until last 5 ft of joint #266. Start taking weight. Normal P/U off slips 425k. Normal S/O 325k. MILl casing hanger and pup joint. P/u landing joint and M/U same. Fill casing using Frank's fill.up tool. Pump a total of 89 bbls at 2-4 bpm with no returns while attempting to move casing. P/U casing off slips. Casing stuck up / down. Max PIU to 675k. Max S/o to 150k. With 89 bbls pumped down pressure went to 2200 psi and jugged. R/D Frank's fill-up tool to allow for higher circulating pressure. Blow down top drive. MIU Halliburton cement head. stage pump rate up to 3200 psi at 500 psi increments and surging back attempting to clear blockage. Broke down at 3200 psi. Continue to attempt to get circulation while working casing. Able to slowly Work casing down and land casing hanger while pumping fluid away with no returns. Max PILl 700k Until hanger entered BOP's. Casing hanger would hang up on the rams. (Note: This summary goes through 0200 hrs Tuesday. Continue to attempt to get circulation while working casing. Able to pump fluid away with no returns. Continue to gain casing string weight while pumping fluid away. Continue to work casing down. Even- tually land casing hanger with 80k down. Still able to pump fluid away at any pump rate with no returns. PJSM - LID Franks casing fill-up tool and 350 ton casing elevators. Clean and prepare rig floor to R/U Schlumberger wireline PJSM - Spot Schlumberger wireline unit and R/U wireline sheaves. Prepare wireline cable head. Bring USlT to rig floor and calibrate same. GIH with Schlumberger USlT. Log USlT on depth. Log out from 10820' to 6000'. Continue to POOH and I. JD USIT. Prepare 1-5 ft 4 1/2" perf gun with 12 spf at 45 degree phase. Hold PJSM with all rig personnel. Bring perf gun to rig floor and verify length between CCL and top shot. Arm perf gun. Perf gun depth at ~7800'. PLQ lost generator power which shut down the wireline unit. Note: The schlumberger wireline unit gets power from pipe rack which is powered by PLQ. Operations trouble shoot PLQ generator problem. Unable to repair generator. PJSM - Drilling rig fired up all 5 generators and back feed power to PLQ. Note: the PLQ supplies power to the pipe rack, G&I, and Halliburton. Monitor back feed power supply between the rig and the PLQ before continue GIH with perf gun. Continue to monitor back feed power between the drilling rig and the PLQ before continue GIH with perf gun. Power appears to be smooth and OK. Log perf gun on depth. Perforate 10811' - 10816'. This put the top shot 10' below the first casing collar above the float collar. Monitor well for losses. No losses. POOH with perf gun and I_/D same. All shots fired. R/D wireline sheaves. R/U 350 ton casing elevators. R/U Halliburton cementing head and cementing hose. Break circulation at 1 bpm at-1000 psi and maintain returns. Slowly stage pump rate up to 12 bpm and maintain full returns. Max gas 1200 units. Balance out the mud in the hole with fluids in the pits to 11.0 ppg. No significant increases in curings across the shakers. Kingak shale appears to be stable with no running. Discuss and receive revised cementing procedure whilw circulating. Perform load test on rig generators. Put one rig mud pump on line along with additional loads from PLQ, Halliburton and G&I. Load before with just rig and PLQ=I.3 meg. Load after adding Halliburton and G&I Time BP Exploration - Northstar NS-31 Daily Operations (I.A.D.C.) Elapsed Code Operations Breakdown (hrs) Time 1300-1730 4.50 1730-2100 3.50 2100-0000 3.00 05/17/01 0000-0130 1.50 0130-0230 1.00 0230-0430 2.00 0430-0530 1.00 0530-0700 1.50 0700-0830 1.50 0830-1000 1.50 1000-1030 0.50 1030-1300 2.50 1300-1430 1.50 1430-1830 4.00 1830-1930 1.00 1930-2100 1.50 2100-0000 3.00 05118101 0000-0300 3.00 0300-0800 5.00 0800-1000 2.00 1000-1730 7.50 1730-2000 2.50 2000-2130 1.50 2130-2330 2.00 2330-0000 0.50 05/19/01 0000-0030 0.50 0030-0530 5.00 0530-0830 3.00 0830-1000 1.50 1000-1100 1.00 1100-1200 1.00 1200-1430 2.50 1430-2330 9.00 2330-0000 0.50 05/20/01 0000-1000 10.00 1000-1100 1.00 1100-1200 1.00 1.7 meg. Total available load -3.0 meg. PJSM for cementing while circulating. Mix and pump the following ( Lead-Premium G Econolite 530 sks 306 bbls Wt 11.2 Yield 3.24 GPS 20.4, Bottom plug, Tail-Premium G 977 sks 200 bbls Wt 15.9 Yield 1.15 GPS 5.0, Top wiper plug, 25 bbls Seawater) Rig displace with mud 729 bbls. Folow proscribed pumping schedule. Cut displacement to Perfs short by 10 bbls ( Leaves-140 bbls cement in casing ). Final pump pressure at 5 bpm = 1100 psi. Shut in pressure = 800 psi. WOC - Displace 13 3~8" x 9 5/8" annulus with one annulus volume. Pump at 1/2 bpm. Broke down at 880 psi to 435 psi. Continue displacing annulus at 1 bpm. Total pumped 193.4 bbls. Final pump pressure -550 psi. WOC - Load and strap drill pipe in pipe shed. Cleaning pits. Clean cellar area. Disconnect turn buckets on BOP's. pull mouse hole and L/D in pipe shed. Latch onto BOP's with bridge crane. Finish WOC 8 hrs. Continue to load and strap drill pipe in pipe shed. Cleaning mud pits. Bleed off casing pressure. Pressure built to 2200 psi. LID cementing head. Clean rig floor area. Split and P/U BOP's. P/U tp 650k at the weight indicator / 540k at the emergency casing slips tp clear the casing collar. Put 2 come-on-alongs around thecasing to center the casing up in the wellhead to be able to drop the slips. Make rough cut on casing and LID hanger. N/D bell nipple and move BOP's out from over wellhead. NIU Vetco gray casing cutter and make final cut on casing. Set seal assembly. N/U BOP's. test seal assembly to 5280 psi ( 80% of casing collapse ) for 15 minutes. Test OK. Change 9 5~8" rams to 2 718" x 5 1/2" VBR's. NIU bell nipple. Set wear bushing. Pressure test 9 5~8" casing to 3000 psi for minutes and chart. Took 7.8 bbls. Test OK. Bled off-200 psi on chart recorder and 10 psi on the digital guage. LID casing elevators. Change from long bails to short bails. P/U drill pipe elevators. PJU misc rig floor equipment. Swap out drill pipe - P/U mule shoe and GIH openended with drill pipe out of derrick. Finish GIH to -10,000' with 5" drill pipe out of derrick. POOH and L/D 40 stds drill pipe. Test choke manifold while POOH. Finish GIH with the remaining 40 stds of the 5" drill pipe out of the derrick. POOH and L/D remaining 5" drill pipe. PJU to freeze protect the 13 3~8" x 9 518" annulus. Drain BOP'S, pullwear bushing, set test plug, and PIU test joint. PLQ power went down. Need PLQ power to transfer diesel through the pipe rack to the rig. PJSM for pumping freeze protect and testing OOP's. PLQ continue to experience problems with PLQ generator. Have the stand-by generator package carry the PLQ only, and have the Rig generators carry the Rig. G&l,and Halliburton. ~ Freeze protect 13 3/8" x 9 5~8" annulus with 108 bbls diesel, 5 bbls Escaid. Max pump pressure 1200 psi. PJD lines for freeze protection. R/U kill line back onto kill line side of BOP's. Test BOP's. Test hydril to 250-3500 psi. test all rams, BOP stack valves, floor valves, top drive valves, kelly hose, and stand pipe to 250-3500 psi. tests OK. Pull test plug and L/D same. AOGCC John Crisp waived witness of BOP test 1430 hrs 5118101. P/U out of pipe shed and GIH with 85 its 5" drill pipe. Rabbit each joint. POOH and rack back 28 stds (84 jts ) of 5" drill pipe. Service top drive, blocks, and crown. Change slip dies in drill pipe air slips and Iron Roughneck. Re-number drill pipe in pipe shed. M/U 8 '/2' BHA and GIH. P/U out of pipe shed and GIH 300 jts of 5" drill pipe. tag cement at 10486' and set 25k weight down. M/U top drive, break circulation, and start reaming down at +100 ftJhr. ( WOB 0-3, Rotary 60, SPM 150 (12.7 bpm), Torque 9k, Drill pipe AV 275), Tag top wiper plug at 10596' ( WOB 10-15, Rotary 60, SPM 180 ( 15.3 bpm), Torque 10k, Drill pipe AV 328 ). Calculated cement top at 10671 '. Continued drilling cement at 60-70 ft/hr through perfs in casing at 10811' - 10816'. Did not hang up going through perfs. Continued drilling cement 60-70 ft/hr down to float collar at 10846'. Drill through float collar. No hard cement below float collar. Continue rotating down to the float shoe at 10933'. Drill through float shoe. Continue rotating down through the 12 ¼" rat hole slowly minimizing the possibility of any cement chunks falling on top of the BHA. No hard cement below the float shoe. Drill 20" of new hole with 10.3 ppg mud. Perform FIT with 10.3 ppg mud while drilling / circulating. No losses. Circulate bottoms up. Pull back up inside the shoe. Blow down top drive. Monitoring well. No losses. Clean L-Pits and #1 mud pit. Time BP Exploration - Northstar NS-31 Daily Operations (I.A.D.C.) Elapsed Code Operations Breakdown (hrs) Time 1200-1500 3.00 1500-1700 2.00 1700-0000 7.00 05/21/01 0000-2200 22.00 2200-2230 0.50 2230-2300 0.50 2300-0000 1.00 05122/01 0000-0030 0.50 0030-0130 1.00 0130-0200 0.50 0200-0800 6.00 0800-0930 1.50 0930-1100 1.50 1100-2000 9.00 2000-0000 4.00 Swap out drilling mud to 9.3 ppg Drill-n-Fluid. Continue to circulate and build 70 bbls 130 Ib/bbl LCM pill. Building -600 bbls 9.3 Drill-n-Fluid in the G&I. Drill 8 '/2" hole from 10965 to 11112'. ( WOB 30-40k, SPM 120-180, SPP 700-800, Rotary 100-120, Torque 10-15k ). No losses. Drill from 11112' to TD 11440' MD, 11280' TVD. TD pick by Geologist/Engineer. WOB 40k, SPM 150 (535 gpm), SPP 1125, Rotary 100, Torque 12-13k. No losses while drilling. Pick top of Kavik 11383' MD. Monitor well. No gain/loss. POOH 6 stds up inside 9 5~8" shoe. Hole slick. No problems. Monitor well no gain/loss. GIH to TD at 11440'. Hole slick. No problems. Circulate 1 ¼ bottoms up. Rotate and reciprocate pipe. Trip Gas = 141 units. BGG drilling/circulating 35 units. Finish circulate/condition prior to POOH to wireline log. Drop Sperry Sun Gyro and pump down same. Pump slug. POOH 6 stands inside of 9 5~8" casing shoe. Blow down top drive. Strap POOH to BHA. Rack back one stand of drill collars. LID in I piece bit, stablizers, and lead collar. Clean rig floor, area. R?U Schlumberger wireline. #1 - Schlumberger wireline logging run. Quad combo - Gamma Ray/Neutron Density/Laterlog/Resistivity. Hole slick no pulls. #2 Schlumberger wireline logging run. Gamma Ray/Dipole Shear Sonic/Array induction Resistivity. Hole Slick. No pulls. sDerrv-sun We, Name: NS-31 Location: Northstar Area DRILLING SERVICES Operatorl BP Exploration Alaska Show Report Report Prepared By' Wayne Hermanson Report Delivered To: Ken Lemley % Depth 8805 ft Gas Units 1503 Mud Chlorides (ppm) = Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 143131 - 15287 = 127844 C1/C2 = 12.9 C2 11550 1609 = 9941 Cl/C3 = 36.5 C3 4394 887 = 3507 Cl/C4 = 104.0 C4 1625 396 = 1229 Cl/C5 = 352.2 C5 533 170 = 363 Production Analysis: Water Non-Producible Hydrocarbons % Depth ft Gas Units Mud Chlorides (ppm) = Flowline Suction Show ppm ppm ppm C1 - = C2 - = C3 - = C4 - = C5 - = Production Analysis: Hydrocarbon Ratios C1/C2 = Cl/C3 = Cl/C4 = Cl/C5 = Water Non-Producible Hydrocarbons I LITHOLOGY: Shale: dark grey to dark brown, occasionally black, trace green grey, fissile, brittle in part, slight to very carbonaceous, firm to hard, soft in part. ISHOW EVALUATION: Pixler plot indicates a non productive !~as zone. Samples indicate that show occurred in a carbonaceous shale - indicating a non productive gas zone. Depth ,MD) 8785 to 8823 ft /TVD) 8679 to 8768 ft Show Report No, 1 Date/Time: 09-May-01 Hydrocarbon Ratios Cl Cl Cl Cl C2 C3 C4 C5 1000.0 NPH 100.0 Gas 10.0 Oil 1.0 '* , Evaluate section for probable production as indicated by the plotted curve within the following: Productive dry gas zones may show only C 1, but abnormally high CI only shows are usually indicative of salt water. If the C1/C2 ratio falls low in the oil section, with the C1/C4 ratio high in the gas section, the zone is probably nonTproductive. If any ratio (C1/C5 excepted ifoil mud is used) is Itmer than a preceding ratio, the zone is probably non-productix e. sperry-sun Well Name:NS-31 Location: Northstar Area DRILLING SERVICES Operator: BP Exploration Alaska Show Report Report Prepared By: Wayne Hermanson Report Delivered To: Ken Lemley % Depth 8892 ft Gas Units 1196 Mud Chlorides (ppm) = Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 111858 - 42431 = 69427 C1/C2 = 13.8 C2 9649 - 4634 = 5015 C1/C3 = 65.7 C3 3271 - 2215 = 1056 C1/C4 = 373.3 C4 1098 - 912 = 186 Cl/C5 = 3306.0 C5 340 - 319 = 21 Production Analysis: Water Non-Producible Hydrocarbons % Depth ft Gas Units Mud Chlorides (ppm) = Flowline Suction Show ppm ppm ppm C1 - = C2 - = C3 - = C4 . = C5 - = Production Analysis: Hydrocarbon Ratios C1/C2 = C1/C3 = C1/C4 = C1/C5 = Water Non-Producible Hydrocarbons I, LITHOLOGY: I Siltstone: buff to light grey, light to medium grey, laminated, micromicaceous in par in part, occasional tuffaceous laminations, firm to hard grading_ ...... to very silty claystone and occasional ultra fine sandstone. [SHOW EVALUATION' Pixler plot indicates a non productive ~las zone. Samples indicate that show occurred in a tight siltstone - indicating a non productive gas zone. Depth (MD) 8880 to 8904 ft (TVD) 8820 to 8843 ft Show Report No. 2 Date/Time: 09-May-01 Hydrocarbon Ratios C1 C1 C1 C1 C2 C3 C4 C5 1000.0 100.0 . - · ._~..~ Gas 10.0 Oil NPH 1.0 , , , Evaluate section for probable production as indicated by the plotted curve within the following: Productive dry gas zones may show only C 1, but abnormally high CI only shows are usually indicative of salt water. If the CI/C2 ratio falls low in the oil section, with the C1,"C4 ratio high in the gas section, the zone is probabl,', non-productive. If any ratio (C1,C5 excepted ifoil mud is used) is lower than a preceding ratio, the zone is probably non-productive. sperry-sun we, Name: NS-31 Location: Northstar Area DRILLING SERVICES Operator: BP Exploration Alaska Show Report Report Prepared By Wayne Hermanson Report Delivered To Ken Lemley ,% Depth 8953 ft Gas Units 1718 Mud Chlorides (ppm) = Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 155419 39544 = 115875 C1/C2 = 13.9 C2 12827 4484 = 8343 C1/C3 = 42.0 C3 4870 2111 - 2759 C1/C4 = 120.0 C4 1799 - 833 = 966 C1/C5 = 418.3 C5 566 - 289 - 277 Production Analysis: Water Non-Producible Hydrocarbons % Depth ft Gas Units Mud Chlorides (ppm) = J Flowline Suction ppm ppm C1 C2 C3 C4 C5 Show ppm Hydrocarbon Ratios = C1/C2 = = Cl/C3 = = Cl/C4 = = Cl/C5 = ... Production Analysis: Water J , J. Non-Producible Hydrocarbons J LITHOLOGY: J Siltstone: buff to light grey, light to medium grey, laminated, micromicaceous in par in part, occasional tuffaceous laminations, firm to hard, grading to very silty claystone and occasional ultra fine sandstone, LSHOW EVALUATION' Pixler plot indicates a ~las zone. Samples indicate that ~as was from a very carbonaceous shale, therefore this zone would be a poor zone for ~las production. Depth ,,MD) 8945 to 8967 ft (TVD) 8880 to 8900 ft Show Report No. 3 Date/Time: 09-May-01 Hydrocarbon Ratios c1 c1 c1 c1 ,,. C2 C3 C4 C5 1000,0 NPH 100.0 10.0 Oil NPH 1.0 Evaluate section for probable production as indicated by the plotted curve within the folloWing: Productive dry gas zones may show only CI, but abnormally high C I only shows are usually indicative of salt water. If the CI/C2 ratio tails Iow' in the oil section, with the C 1/C4 ratio high in the gas section, the zone is probably non-productive. If any ratio (CIC5 excepted ifoil mud is used) is lm,,er than a preceding ratio, the zone is probabl.v non-producti', e. sperry-sun Name: NS-31 Location' Northstar Area DRILLING SERVICES Operator: BP Exploration Alaska Show Report Report Prepared By: Wayne Hermanson Report Delivered To: Ken Lemley Depth 9070 Flowline ppm C1 680748 C2 59357 C3 16138 C4 4763 751 C5 1670 301 Production Analysis: Depth 9132 ft Gas % ft Gas Units 8704 Mud Chlorides (ppm) = Suction Show ppm ppm Hydrocarbon Ratios 32128 = 648620 C1/C2 = 11.6 3528 = 55829 C1/C3 = 44.9 1683 = 14455 C1/C4 = 161.7 = 4012 C1/C5 = 473.8 = 1369 Water Non-Producible Hydrocarbons % Units 6593 Mud Chlorides (ppm) = Flowline Suction ppm ppm C1 579953 32128 C2 41039 - 3528 C3 11031 1683 C4 3345 - 751 C5 1057 - 301 Show ppm Hydrocarbon Ratios = 547825 C1/C2 = 14.6 = 37511 C1/03 = 58.6 = 9348 Gl/C4 = 211.2 = 2594 C1/C5 = 724.6 = 756 Production Analysis: Water Non-Producible Hydrocarbons I LITHOLOGY: Sand: Clear to traslucent, tan, trace green, very fine to fine, angular to sub rounded, moderately sorted, unconsolidated in silty matrix, very slighty calcareous, trace glauconite, trace dull orange fluorescence, trace slow very faint dull yell cut fluorescnce. ISHOW EVALUATION: Pixler plot indicates a productive ~las zone. Samples also indicate a favorable production environment. This zone is rated as fair to good for gas production. Depth (MD) 9060 to 9152 ft (TVD) 8986 to 9072 ft Show Report No. 4 Date/Time: 10-May-01 Hydrocarbon Ratios C1 C1 Cl C1 C2 C3 c4 c5 1000.0 NPH .... 100.0 ':::.. :: :,;,:__~; -_-z.-:: :::=:_::~::::~: ;~_2.~_~__-;."~ ---7;.- -~-.3'-'----- .......... .,~._.1~ ....................... Gas 10.0 Oil NPH .; --- --- --' ---J'. '. ,,-- 1.0 Evaluate section for probable production as indicated by the plotted curve within the following: Productive dry gas zones may show only C 1, but abnormally high CI only shows are usually indicative of salt water. If the CI/C2 ratio tails Iow in the oil section, with the C1/C4 ratio high in the gas section, the zone is probably non-productive. If any ratio (C1,"C5 excepted ifoil mud is used) is lower than a preceding ratio, the zone is probably non-productive. sperry-sun w.,, Name: NS-31 Location: Northstar Area DRILLING SERVICES Operator: BP Exploration Alaska Show Report Report Prepared By: Wayne Hermanson Report Delivered To: Ken Lemley Depth 9070 Flowline ppm C 1 108222 C2 15242 C3 8632 C4 4566 C5 2496 Production Analysis: % ft Gas Units 8704 Mud Chlorides (ppm) = ss Suction Show ppm ppm Hydrocarbon Ratios - 2757 = 105465 Cl/C2 = 7.4 - 1006 = 14236 C1/C3 = 13.8 - 1007 = 7625 C1/C4 = 28.2 - 828 = 3738 C1/C5 = 57.7 - 667 = 1829 Water Non-Producible Hydrocarbons Depth ft Gas Units Mud Chlorides (ppm) = Flowline Suction ppm ppm Show ppm Hydrocarbon Ratios C1/C2 = C1/C3 = C1/C4 = C1/C5 = Water Non-Producible Hydrocarbons C1 C2 - C3 C4 C5 Production Analysis: I LITHOLOGY: I Sand: Clear to traslucent, tan, trace green, very fine to fine, angular to sub rounded, moderately sorted, unconsolidated in silty matrix, very slighty calcareous, trace glauconite, trace dull orange fluorescence, trace slow very faint dull yell cut fluorescnce. SHOW EVALUATION: Pixter plot indicates a productive ~las zone. Samples also indicate a favorable production environment. This zone is rated as fair to good for gas production. Analysis from Steam Still Depth /MD) 9060 to 9152 ('l-VD) 8986 to 9072 Show Report No. 4SS Date/Time: 10-May-01 Hydrocarbon Ratios Cl C1 C1 C1 C2 C3 C4 C5 1000.0 NPH 100.0 Gas 10.0 Oil NPH 1.0 Evaluate section for probable production as indicated by the plotted curve within the following: Productive dry gas zones may show only C 1, but abnormally high C I only.shows are usually indicative of salt water. If the C1/C2 ratio falls low in the oil section, with the C1/C4 ratio high in the gas section, the zone is probably non-productive. lt"anx ratio tC 1. C5 excepted ir'oil mud is used)is loxver than a preceding ratio, the zone is probabl? non-productive. l.. sperry-sunWell Name: NS-31 Location: Northstar Area DRILLING SERVICES Operator: BP Exploration Alaska Show Report Report Prepared By: Wayne Hermanson Report Delivered To: Ken Lemley % Depth 10933 ft Gas Units 1200 Mud Chlorides (ppm) = ss Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 39649 - 2757 = 36892 C1/C2 = 6.7 C2 6548 - 1006 = 5542 C1/C3 = 10.7 C3 4445 - 1007 = 3438 C1/C4 = 21.2 C4 2570 - 828 = 1742 C1/C5 = 48,8 C5 1423 - 667 = 756 Production Analysis: Water Non-Producible Hydrocarbons % Depth ft Gas :Units Mud Chlorides (ppm) = Flowline Suction ppm ppm C1 - C2 - C3 C4 C5 Show ppm Hydrocarbon Ratios = C1/C2 = = Cl/C3 = = C1/C4 = = C1/C5 = Production Analysis: Water Non-Producible Hydrocarbons I LITHOLOGY: Sandstone: very light gray, light gray, white in part, extra fine to very fine grain, subangular, poorly sorted, predominately as interbeds and imbeds in very silty clay, laminated clay in part, glauconite, trace calcareous in part, soft to very friable, very dull and moderate yellow-white sample fluorescence, light straw colored white light cut-residual, very dull moderately fast yellow-white cut fluorescence [SHOW EVALUATION: Pixler plot indicates a productive ~las-light oil zone. Samples also indicate a favorable production environment. This zone is rated as fair to good for gas-light oil production. Analysis from Steam Still Depth i MD) 10904 to 10942 ft ('FVD) 10752 to 10790 ft Show Report No. 5SS Date/Time: 13-May-01 Hydrocarbon Ratios C1 C1 C1 C2 C3 C4 Cl 1000.0 NPH 100.0 10.0 Oil Evaluate section for probable production as indicated by the plotted curve within the following: Productive dry gas zones may show only C 1, but abnormally high C1 only shows are usually indicative of salt water. If the CI/C2 ratio tails low in the oil section, with the CI/C4 ratio high in the gas section, the zone is probably non-productive. If any ratio (C1/C5 excepted ifoil mud is used) is lower than a preceding ratio, the zone is probably non-productive. sperry-sun Name: NS-31 Location: Northstar Area DRILLING SERVICES Operator: BP Exploration Alaska Show Report Report Prepared By: Doug Wilson Report Delivered To: Ken Lemley Depth 11076 ft Flowline Suction ppm ppm C 1 44594 1392 % Gas Units 839 Show ppm = 432O2 C2 8997 394 = 8603 C3 7816 435 = 7381 C4 5795 338 = 5457 C5 3269 195 = 3074 Mud Chlorides (ppm) = 20000 Production Analysis: Water % Depth 11120 ft Gas Units 363 Hydrocarbon Ratios Cl/C2 = 5.0 Cl/C3 = 5.9 C1/C4 = 7.9 C1/C5 = 14.1 Non-Producible Hydrocarbons Mud Chlorides (ppm) = 20000 Flowline Suction Show ppm ppm ppm C1 11630 1392 = 10238 C2 2801 394 = C3 2901 435 = C4 2369 338 = C5 1449 - 195 Production Analysis: Hydrocarbon Ratios Cl/C2 = 4.3 2407 Cl/C3 = 4.2 2466 Cl/C4 = 5.0 2031 Cl/C5 = 8.2 1254 Water Non-Producible Hydrocarbons !LITHOLOGY: I SANDSTONE: TRANSLUCENT, WHITE, LIGHT GRAY, VERY FINE TO COARSE GRAIN, ANGULAR TO SUBROUNDED, MODERATELY TO POORLY SORTED, PREDOMINATELY QUARTZ CEMENT, OCCASIONALLY CALCAR- EOUSLY CEMENTED, ABUNDANT CHERT, TRACE PYRITE, 30% DULL YELLOW SAMPLE FLUORESCENCE, OCCASIONAL VERY FAINT DULL ORANGE CUT FLUORESCENCE. SHOW EVALUATION' Pixler plot indicates a productive oil zone. Samples indicate that show zone would produce light oil Depth (MD) 11065 to 11390 ft (TVD) 10913 to 11236 ft Show Report No. 6A Date/Time: 20-May-01 Hydrocarbon Ratios c1 c1 Cl c1 c2 c3 c4 c5 1000.0 NPH .............................................. 100.0 . :2.2_.__i .............. ~L.'_'..~ ._-~' . ..... -.-ZL.__~ .... Gas ?_ ............ - .... [.~TE _-:_.....-__:-- _ ..... : Oil NPH 1.0 Evaluate section for probable production as indicated by the plotted curve within the t'ollowing: Productive dry gas zones may show only C 1, but abnormally high C I only shows are usually indicative of salt water. b. If the C1/C2 ratio tails low' in the oil section, with the C1/C4 ratio high in the gas section, the zone is probably non-productive. If an.v ratio {C1/C5 excepted ifoil mud is used)is Io,,,,er than a preceding ratio, the zone is probably non-productive. sperry-sun Name: NS-31 Location: Northstar Area DRILLING SERVICES Operator' BP Exploration Alaska Show Report Report Prepared By: Doug Wilson Report Delivered To: Ken Lemley % Depth 11200 ft Gas Units 240 Mud Chlorides (ppm) '- 20000 Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 10521 1392 = 9129 C1/C2 = 4.7 C2 2326 394 = 1932 C1/C3 = 4.5 C3 2454 435 = 2019 C1/C4 = 4.9 C4 2210 - 338 = 1872 C1/C5 = 7.1 ,,, C5 1483 - 195 = 1288 Production Analysis: Water Non-Producible Hydrocarbons % Depth 11280 ft Gas Units 153 Mud Chlorides (ppm) = 20000 Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 14261 1392 = 12868 C1/C2 = 6.6 C2 2336 394 = 1942 C1/C3 = 8.3 C3 1986 435 = 1551 Cl/C4 = 10.1 C4 1607 338 = 1269 Cl/C5 = 12.3 C5 1250 195 = 1055 Production Analysis: Water Non-Producible Hydrocarbons J LITHOLOGY: J SANDSTONE: TRANSLUCENT, WHITE, LIGHT GRAY, VERY FINE TO COARSE GRAIN, ANGULAR TO SUBROUNDED, MODERATELY TO POORLY SORTED, PREDOMINATELY QUARTZ CEMENT, OCCASIONALLY CALCAR- EOUSLY CEMENTED, ABUNDANT CHERT, TRACE PYRITE, 30% DULL YELLOW SAMPLE FLUORESCENCE, OCCASIONAL VERY FAINT DULL ORANGE CUT FLUORESCENCE. ISHOW EVALUATION' Pixler plot indicates a productive oil zone. Samples indicate that show zone would produce light oil Depth (MD) (TVD) Date/Time: 11065 to 11390 10913 to 11236 Show Report No. 20-May-01 Hydrocarbon Ratios C1 C1 C1 C2 C3 C4 C1 1000.0 NPH 100.0 Gas 10.0 Oil NPH 1.0 Evaluate section for probable production as indicated by the plotted curve within the following: Productive dry gas zones may show only C1, but abnormally high C1 only shows are usually indicative of salt water. If the CI/C2 ratio falls Iow in the oil section, with the C!/C4 ratio high in the gas section, the zone is probably non-productive. If any ratio (C1/C5 excepted ifoil mud is used) is lower than a preceding ratio, the zone is probably non-productive. Mudlogger's Morning Report Customer: BP Alaska Report No.: 1 Well: Northstar NS 31 Date: 4/25/01 Area: North Slope Depth 0 Lease: Northstar NS 31 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: Prepare to drill Job No.: AK AM 10142 Report For: Joe Polya Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. fi/hr fi/hr ( ~ft/hr @ ) Pump 1 spm DH flow gpm Gas* units unit,, ( ~ units @ ) Pump 2 spm Total flow gpm Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In Mud Wt Out 9.30 ppg Visc 28 secs APl flit ~ml HTHP~ml Mud Wt at Max Gas ppg 9.30 ppg PV 1 cP YP Ibs/100ft2 Gels \ Ibs/100ft2 pH Sd % Bit No.: Type: Wt On Bit: RPM: Bit Size: Jets: \ \ \ \ \ TFA: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depthi Short Trip Depth Tight Spots: to ft Trip Gas: Mud Cut: ~PPg Trip Cl: ppm ft Short Trip Gas: Mud Cut: ~PPg Short Trip Cl: ppm to to Feet of Fill on Bottom: ft Current Lithology: % % % %LCM ft units ft units ft units Connection Gas and Mud Cut ppg ~ ft__ units ~PPg ft units ppg ppg ,. . ft units ~PPg ft units ppg ppg ~ ft ~ units ppg ft units ppg Depth to before Drilling Breaks Drill Rate Gas % Lithology during after before during after Sst Sltst Sh Lst 24 hour accumulation of Steel Fillings from Possum Belly Magnets: Dscription of fillings: grams 24 hr Recap: Cont to prep for rig move. Move Rig to NS-31, Prep to Drill Surface hole. Logging Engineer: WAYNE.HERMAN,SON/MARK LINDLOFF 10000 units = 100% Gas In A'i"r spepp -sun Mudlogger's Morning Report Customer: BP Alaska Report No.: Well: Northstar NS 31 Date: Area: North Slope Depth Lease: Northstar NS 31 Footage Last 24 hrs: Rig: Nabors 33E Rig Activity: Job No.: AKAM 10142 Report For: Shows: 2 4/26/01 230' 31' Prepare to drill Joe Polya Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 f't/hr 210 fi/hr ( 360 ffJhr @ 231 ) Pump 1 100 spm DH flow Gas* 0 units 0 unit,, ( 0 units @ 0 ) Pump 2 100 spm Total flow TempOut DegF ( degF@ ) Pump3 spm AV~rsr Pump Pres 500 psi AV @ DC 710 gpm fpm fpm Mud Wt In 9.40 ppg Visc 128 secs APl flit 10.8 mi HTHP 0.0 mi Mud Wt at Max Gas 9.4 ppg Mud WtOut 9.40 ppg PV 17 cP YP 75 Ibs/100ft2 Gels 21 \ 32 Ibs/100ft2 pH 9.0 Sd 0.1 % Bit No.: 1 Type: MX-C1 Bit Size: 16 Wt On Bit: 10/15 RPM: 60 Hrs. On Bit: Jets: 12 \ 22 \ 22 \ 22 \ \ TFA: 1.2240 Total Revs on Bit: Footage for Bit Run 31' Trip Depth: ft Trip Gas: Mud Cut: ~PPg Trip Cl: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ~PPg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 90 % GRVL 10 % SD % % %LCM Connection Gas and Mud Cut ~ ft units , ppg ~ ft ~ units __ppg ft units ppg ~ ft __ units ~ ppg ~ ft ~ units ~ ppg ft units ppg ~ ft units ~PPg ~ ft ~ units ~PPg ft units ppg Depth to before Drilling Breaks Drill Rate Gas % Lithology during after before during after Sst Sltst Sh Lst 24 hour accumulation of Steel Filings from Possum Belly Magnets: Dscription of fillings: NO METAL FILINGS WERE OBSERVED 0 grams 24 hr Recap: Re-oreint rig over hole. Make up diverter, Make up BHA #1, drill out ice plug, Spud Drill F/199 T/231, Circulate hole clean. POOH to make up BHA #2 Logging Eng.(neer: WAYNE HERMANSON/MARK LINDLOF'F- * '"i0000 units= 100% Gas In Air Mudlogger's Morning Report Customer: BP Alaska Report No.: 3 Well: Northstar NS 31 Date: 4/27/01 Area: North Slope Depth 1163' Lease' Northstar NS 31 Footage Last 24 hrs' 1132' Rig: Nabors 33E Rig Activity: Drillin~l Job No.: AK AM 10142 Report For: Joe Polya Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr 185 ft/hr ( 714 ffJhr @ 1195 ) Pump 1 100 spm DH flow gpm Gas* 0 units 0 unit,, ( 1 units @ 1192 ) Pump 2 100 spm Total flow 710 gpm Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ rsr fpm Pump Pres 1000 psi AV @ DC fpm Mud Wt In 9.50 ppg Visc 185 secs APl flit 12.2 mi HTHP 0.0 mi Mud Wt at Max Gas 9.5 ppg Mud WtOut 9.50 ppg PV 30 cP YP 69 Ibs/100ft2 Gets 22 \ 28 Ibs/100ft2 pH 8.4 Sd 1.5 % Bit No.: 1 Type: MX-C1 Bit Size: 16 Wt On Bit: 5/15 RPM: 50 Hrs. On Bit: Jets: 12 \ 22 \ 22 \ 22 \ \ TFA: 1.2240 Total Revs on Bit: Footage for Bit Run 864' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip Cl' ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 10 % GRVL 70 % SD 20 % CLY % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft __ units ~ ppg ft __ units ~ ppg ft __ units .... ppg Depth to before Drilling Breaks Drill Rate Gas % Lithology during after before 'during after Sst Sltst Sh Lst 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Trace of short slivers 2 grams 24 hr Recap: Repair drag chain in shakers that transports cuttings to G&I Plant, Cont Drilling 16" hole. F/231 T/1163, periodically running Gyro's. Logging Engineer: WAYNE HERMANSON/MARK LINDLOFF * 10000 units: 100% Gas In Air Mudlogger's Morning Report Customer: BP Alaska Report No.: 4 Well: Northstar NS 31 Date: 4/28101 Area: North Slope Depth 3249' Lease: Northstar NS 31 Footage Last 24 hrs: 2117' Rig: Nabors 33E Rig Activity: Circulatin9 Job No.: AK AM 10142 Report For: Joe Polya Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 fi/hr 195 fi/hr ( 646 fi/hr @ 3249' ) Pump 1 100 spm DH flow gpm Gas* 9 units 27 unit., ( 88 units @ 2156 ) Pump 2 100 spm Total flow 710 gpm Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ rsr fpm Pump Pres 1450 psi AV @ DC fpm Mud Wtln 9.60 ppg Visc 54 secs APl flit 9.1 ml HTHP 0.0 mi Mud Wt at Max Gas 9.6 ppg Mud WtOut 9.60 ppg PV 17 cP YP 27 Ibs/100ft2 Gels 14 \ 19 Ibs/100ft2 pH 8.1 Sd 0.75 % Bit No.' 1 Type: MX-C1 Bit Size: 16 Wt On Bit: 10/30 RPM' 50 Hrs. On Bit: 18.9 Jets: 12 \ 22 \ 22 \ 22 \ \ TFA: 1.2240 Total Revs on Bit: Footage for Bit Run 3018 Trip Depth: ft Trip Gas: Mud Cut:, __ ppg Trip Ch 22000 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: __ ppg Short Trip CI: ppm Tight Spots: to ~ to ~. to ~ Feet of Fill on Bottom: ~ ft Current Lithology: 40 % SD 60 % CLY % % %LCM Connection Gas and Mud Cut ~ ft __ units ~ ppg ~ ft __ units __ ppg ft __ units ~ ppg ~ ft __ units ~ ppg ~ ft __ units __ ppg ft __ units ~ ppg ~ ft __ units ppg ~ ft __ units __ppg ft __ units ~ppg Depth to Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh Lst 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Trace of short slivers 2 grams 24 hr Recap' Drilled to surface casing point 3249'. Lost 75 BBLS at 2745'. Pumped sweep around. Currently/POOH. If it pulls tight we will RIH to clean it out. If we pull out with no problems we will rig up for casing. Logging Engineer: WAYNE HERMANSON/MARK LINDLOFF * 10000 units = 100% Gas In Air sperry-sun Mudlogger's Morning Report Customer: BP Alaska Report No.: 5 Well: Northstar NS 31 Date: 4/29/01 Area: North Slope Depth 3249' Lease: Northstar NS 31 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: Cementin~l Job No.: AKAM 10142 Report For: Joe Polya Shows: Current R.O.P. 0 ft/hr Gas* 0 units Temp Out Deg F 24 hr Avg 24 hr Max Pump and Flow Data 0 fi/hr ( 0 fi/hr @ 0 ) Pump 1 spm DH flow gpm 0 unit., ( 0 units @ 0 ) Pump 2 0 spm Total flow gpm ( ~degF@ ) Pump3 spm AV@rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.60 ppg Visc 53 secs APl flit 9.2 mi HTHP 0.0 mi Mud Wt at Max Gas 9.6 ppg Mud WtOut 9.60 ppg PV 19 cP YP 30 Ibs/100ft2 Gels 12 \ 14 Ibs/100ft2 pH 7.5 Sd 0.75 % Bit No.: 1 Type: MX-C1 Bit Size: 16 Wt On Bit: 0.00 RPM: 0 Hrs. On Bit: 18.9 Jets: 12 \ 22 \ 22 \ 22 \ \ TFA: 1.2240 Total Revs on Bit: Footage for Bit Run 3018 Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: Mud Cut: ppg Trip Cl: 22000 ppm ft Short Trip Gas: Mud Cut: ppg Short Trip Cl: ppm to to to Feet of Fill on Bottom: ft Current Lithology: 40 % SD 60 % CLY % % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ~ ft __ units , ppg ff units __ ppg ft __ units ~ ppg ~ ff __ units __ ppg fi__ units __ ppg ff __ units ~ ppg Depth to Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh Lst 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: No metal was observed on the magnets 0 grams 24 hr Recap: Cont POOH, P/U Casing Tools, Run 13.38 casing to 3237'. Lay down Casing tool, Getting ready to Cement Logging Engineer: WAYNE HERMANSON/MARK LINDLOFF 10000 units = 100% Gas In Air Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska Northstar NS 31 North Slope Northstar NS 31 Nabors 33E AK AM 10142 Report No.: 6 Date: 4/30/01 Depth 3249' Footage Last 24 hrs: 0 Rig Activity' Nipple Up Report For: Joe Polya Shows: Current 24 hr Avg R.O.P. 0 fi/hr 0 ft/hr ( Gas* 0 units 0 unit,, ( Temp Out 60 Deg F ( 24 hr Max 0 fi/hr @ 0 0 units @ 0 deg F @ Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 0 spm Total flow gpm Pump 3 spm AV @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.60 ppg Mud Wt Out 9.60 ppg i Bit No.' 1 Type: Wt On Bit: 0.00 RPM: Visc 51 secs APl flit 9.8 mi HTHP 0.0 mi Mud Wt at Max Gas 9.6 ppg PV 18 cP YP 27 Ibs/100ft2 Gels 14 \ 20 Ibs/100ft2 pH 9.3 Sd 0.5 % MX-C1 Bit Size: 16 Jets: 12 \ 22 \ 22 \ 22 \ \ TFA: 1.2240 0 Hrs. On Bit: 18.9 Total Revs on Bit: Footage for Bit Run 3018 Trip Depth: Short Trip Depth Tight Spots: to fi Trip Gas: Mud Cut: ppg Trip CI: 21000 ppm ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm to to Feet of Fill on Bottom: ft Current Lithology: 40 % SD 60 % CLY % % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ~PPg ft units ppg ft units ~PPg ~ ft __ units ~PPg ft __ units ~ ppg ft __ units ~PPg Depth to before Drilling Breaks Drill Rate Gas % Lithology during after before during after Sst Sltst Sh Lst 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: No metal was observed on the magnets 0 grams 24 hr Recap' Cir casing at 10 bpm, no losses. Cement first sta~le as per well plan, Open cementer and circulate hole. Pump second sta~le and cemented to surface. Nippled down diverter. Nippting up BOP. Logging Engineer: WAYNE HERMANSON/MARK LINDLOFF * 10000 units = 100% Gas In Air j_, spepp -sun Mudlogger's Morning Report Customer: BP Alaska Report No.: 7 Well: Northstar NS 31 Date: 5/1/01 Area: North Slope Depth 3249' Lease: Northstar NS 31 Footage Last 24 hfs: 0 Rig: Nabors 33E Rig Activity: TIH Job No.: AK AM 10142 Report For: Joe Polya Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 fi/hr 0 fi/hr ( 0 fi/hr @ 0 ) Pump 1 spm DH flow gpm Gas* 0 units 0 unit,,( 0 units @ 0 ) Pump 2 0 spm Total flow gpm TempOut 45 DegF ( ~degF@ ) Pump3 spm AV@rsr fpm Pump Pres psi AV @ DC fpm. Mud Wt In 9.30 ppg Visc 39 secs APl flit 25.0 mi HTHP 0.0 mi Mud Wt at Max Gas 9.3 ppg MudWtOut 9.30 ppg PV 14 cP YP 13 Ibs/100ft2 Gels 5 \ 11 Ibs/t00ft2 pH 10.4 Sd 0.5 % Bit No.: 2 Type: MX-C1DX Bit Size: 12 1/4 Wt On Bit: 0.00 RPM: 0 Hrs. On Bit: 0.0 Jets: 16 \ 16 \ 20 \ 20 \ \ TFA: 1.0060 Total Revs on Bit: Footage for Bit Run 0 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 21000 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 40 % SD 60 % CLY % % %LCM Connection Gas and Mud Cut ~ ft __ units ~ ppg ft units ppg ft units ppg ~ ft __ units ~ ppg ft units ppg ft units ppg ....... ft ~ units ~PPg ft units ppg ft units ppg Depth to before Drilling Breaks Drill Rate Gas % Lithology during after before during after Sst Sltst Sh Lst 24 hour accumulation of Steel Filings from Possum Belly Magnets: 544 Description of fillings: Mostly shavin~Is and splinters, some curl)/Q's pieces of metal. grams 24 hr Recap: Continue nippling up BOP's. Perform BOP test, passed, Make up @HA #3, RIH to 3154' md. Logging Engineer: WAYNE HERMANSON/MARK LINDLOFF * 10000 units =100% Gas In Air i. sp r r', -sur-I Mudlogger's Morning Report Customer: BP Alaska Report No.: 8 Well: Northstar NS 31 Date: 5/2/01 Area: North Slope Depth 4785 Lease: Northstar NS 31 Footage Last 24 hfs: 1536' Rig' Nabors 33E Rig Activity: Drilling Job No.: AK AM 10142 Report For: Joe Polya Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data R.©.P. 189 ft/hr 189 fi/hr ( 300 fi/hr @ 4783 ) Pump 1 105 spm DH flow gpm Gas* 26 units 32 unit,, ( 123 units @ 4734 ) Pump 2 106 spm Total flow 750 gpm TempOut 75 DegF ( ~degF@ ) Pump3 spm AV@rsr fpm Pump Pres 1450 psi AV @ DC fpm Mud Wt In 9.30 ppg Visc 46 secs APl flit 6.0 mi HTHP 0.0 mi Mud Wt at Max Gas 9.3 ppg Mud WtOut 9.30 ppg PV 14 cP YP 22 Ibs/100ft2 Gels 6 \ 1'0 Ibs/100ft2 pH 8.8 Sd 0.1 % Bit No.: 2 Type: MX-CIDX Bit Size: 12 1/4 Jets: 16 \ 16 \ 20 \ 20 \ \ TFA: 1.0060 Wt On Bit: 25.00 RPM: 80 Hrs. On Bit: 0.0 Total Revs on Bit: Footage for Bit Run 1536' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 56000 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 20 % SD 70 % CLY 10 % slst % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ~ units ppg ft units ppg ft units ppg ft~ units , ppg ft units ppg ft units ppg Depth before Drilling Breaks Drill Rate Gas % Lithology during after before during after Sst Sltst Sh Lst 24 hour accumulation of Steel Filings from Possum Belly Magnets: 680 Description of fillings: Mostly shavin~Is and splinters, some curly Q's pieces of metal. grams 24 hr Recap: Test Casin~l, passed, drill out cement and float equipment. Perform Leak Off Test 15.3 EMW, Displace mud · Drill F/3269' T/4785' Logging Engineer: WAYNE HERMANSON/MARK LINDLOFF * 10000 units =100% Gas ln Air Mudlogger's Morning Report Customer: BP Alaska Report No.: 9 Well: Northstar NS 31 Date: 5/3/01 Area: North Slope Depth 5742 Lease: Northstar NS 31 Footage Last 24 hrs: 957' Rig: Nabors 33E Rig Activity: Drilling Job No.: AK AM 10142 Report For: Joe Polya Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 31.4 fi/hr 166 fi/hr ( 349 fi/hr @ 5741 ) Pump 1 104 spin DH flow gpm Gas* 117 units 99 unit,,( 1458 units @ 5705 ) Pump 2 105 spm Total flow 750 gpm TempOut 75 DegF ( ~degF@ ) Pump3 spm AV~rsr fpm Pump Pres 1600 psi AV @ DC fpm Mud Wt In 9.30 ppg Visc 46 secs APl flit 5.4 mi HTHP 0.0 mi Mud Wt at Max Gas 9.3 ppg MudWtOut 9.30 ppg PV 11 cP YP 21 Ibs/100ft2 Gels 6 \ 9 Ibs/100ft2 pH 8.5 Sd 0.1 % Bit No.' 2 Type: MX-CIDX Bit Size: 12 1/4 Jets: 16 \ 16 \ 20 \ 20 \ \ TFA: 1.0060 Wt On Bit: 30.00 RPM: 80 Hrs. On Bit: 0.0 Total Revs on Bit: Footage for Bit Run 2493 Trip Depth: ft Trip Gas: Mud Cut: ~PPg Trip CI: ppm Short Trip Depth 5350 ft Shod Trip Gas: 1458 Mud Cut: ppg Shod Trip CI: 50000 ppm Tight Spots: 4691' to 3180' to to Feet of Fill on Bottom: ft Current Lithology: 50 % sd 10 % clyst 40 % slst % %LCM Connection Gas and Mud Cut ft __ units ~ ppg ~ ft __ units __ ppg ft units ppg ff __ units ~ ppg ~ ft __ units __ ppg ff units ppg ff __ units ~ ppg ~ ft __ units __ ppg ff units ppg Depth before Drilling Breaks Drill Rate Gas % Lithology during after before during after Sst SItst Sh Lst 24 hour accumulation of Steel Filings from Possum Belly Magnets: 14 Description of fillings: Mostly shavin~Is and splinters, some curl), Q's pieces of metal. oz 24 hr Recap: Drill F/4785', T5350', POOH T/4691' Back reamed F4691 T 3180, Serviced top drive, cut and slip drill line RIH F/3180'. T5350", with 1458 units of TG recorded. Dritlin~l F/5350'. T/5742' Logging Engineer: WAYNE HERMANSON/MARK LINDLOFF 10000 units = 100%.Gas In Air Mudlogger's Morning Report Customer: BP Alaska Report No.: 12 Well: Northstar NS 31 Date: 5/6/01 Area: North Slope Depth 7361 Lease: Northstar NS 31 Footage Last 24 hrs: 403 Rig: Nabors 33E Rig Activity: POOH Job No.: AK AM 10142 Report For: Joe Polya Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 fi/hr 68 fi/hr ( 163 fi/hr @ 6992 ) Pump 1 110 spm DH flow gpm Gas* 0 units 88 unit,, ( 613 units @ 6959 ) Pump 2 115 spm Total flow 800 gpm TempOut 75 DegF ( ~degF@ ) Pump3 spm AV@rsr fpm Pump Pres 0 psi AV @ DC fpm Mud Wt In 9.40 ppg Visc 45 secs APl flit 6.1 mi HTHP 0.0 mi Mud Wt at Max Gas ppg Mud Wt Out 9.40 ,PPg PV 10 cP YP 19 Ibs/100ft2 Gels 7 \ 12 Ibs/100ft2 pH 8.6 Sd 0.25 % Bit No.: 3 Type: DS97+GNV Bit Size: 12 1/4 Jets: 15 \ 15 \ 15 \ 15 \ 15 \ 15 TFA: 1.0350 Wt On Bit: 5/10 RPM: 50 Hrs. On Bit: 5.9 Total Revs on Bit: Footage for Bit Run 403 Trip Depth: 6958 ft Trip Gas: 613 Mud Cut: ~ppg Trip Cl: 48500 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 70 % CLST 25 % SLST % % %LCM Connection Gas and Mud Cut ~ ft__ units __ ppg ~ ft __ units ~ ppg ft units ppg ~ ft ~ units ppg , ft units ~PPg ft units ppg , , ft ~ units .... ppg ~ ft ~ units ~ ppg ft units ppg Depth to Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh Lst 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Jigsaw edged curl), Q's, Shavings and splinters. 6.8 oz 24 hr Recap: Cont RIH with new BHA. Start Drilling F/6959 T/6979, Lost MWD Signal, Tried to establish communication with the tool. Failed. Drilled to drop point 7361' POOH to change out MWD Tool. Logging Engineer: WAYNE HERMANSON/MARK LINDLOFF * 10000 units =100% Gas In Air Mudlogger's Morning Report Customer: BP Alaska Report No.: 12 Well: Northstar NS 31 Date: 5/6/01 Area: North Slope Depth 7361 Lease: Northstar NS 31 Footage Last 24 hrs: 403 Rig: Nabors 33E Rig Activity: POOH Job No.: AK AM 10142 Report For: Joe Pol~/a Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 fi/hr 68 fi/hr ( 163 fi/hr @ 6992 ) Pump 1 110 spm DH flow gpm Gas* 0 units 88 unit,, ( 613 units @ 6959 ) Pump 2 115 spm Total flow 800 gpm Temp Out 75 Deg F ( deg F @ ) Pump 3 spm AV @ rsr fpm Pump Pres 0 psi AV @ DC fpm Mud Wt In 9.40 ppg Visc 45 secs APl flit 6.1 mi HTHP 0.0 mi Mud Wt at Max Gas ppg Mud Wt Out 9.40 ppg PV 10 cP YP 19 Ibs/100ft2 Gels 7 \ 12 Ibs/100ft2 pH 8.6 Sd 0.25 % Bit No.: 3 Type: DS97+GNV Bit Size: 12 1/4 Jets: 15 \ 15 \ 15 \ 15 \ 15 \ 15 TFA: 1..0350 Wt On Bit: 5/10 RPM: 50 Hrs. On Bit: 5.9 Total Revs on Bit: Footage for Bit Run 403 Trip Depth: 6958 ft Trip Gas: 613 Mud Cut: ppg Trip CI: 48500 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 70 % CLST 25 % SLST % % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft . units ppg ft units ppg ft __units __PPg ft units ~PPg Depth to before Drilling Breaks Drill Rate Gas % Lithology during after before during after Sst Sltst Sh Lst 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Ji~lsaw edged curl}, Q's, Shavings and splinters. 6.8 oz 24 hr Recap: Cont RIH with new BHA, Circulated, 613 units of TG observed at bottoms up. . Start Drilling F/6959 T/6979, Lost MWD Signal, Tried to establish communication with the tool. Failed. Drilled to drop point 7361'. POOH to change out MWD Tool. Logging Engineer: WAYNE HERMANSON/MARK LINDLOFF * 10000 .units = 100% Gas In Air Mudlogger's Morning Report Customer: BP Alaska Report No.: 15 Well: Northstar NS 31 Date: 5/9/01 Area: North Slope Depth 9329' Lease: Northstar NS 31 Footage Last 24 hrs: 761' Rig: Nabors 33E Rig Activity: Drilling] Job No.: AK AM 10142 Report For: Paul Lockwood Shows: None Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 50 fi/hr 46.1 fi/hr ( 180 fi/hr @ 9130 ) Pump 1 106 spm DH flow gpm Gas* 400 units 478 unit,'( 8704 units @ 9070 ) Pump 2 108 spm Total flow 735 gpm TempOut DegF ( ~degF@ ) Pump3 spm AV@rsr fpm Pump Pres 2575 psi AV @ DC fpm Mud Wt In 9.80 ppg Visc 44 secs APl flit 5.6 mi HTHP 11.8 mi Mud Wt at Max Gas 8.7 ppg Mud WtOut 9.80 ppg PV 11 cP YP 27 Ibs/100ft2 Gels 11 \ 18 Ibs/100ft2 pH 8.3 Sd 0.25 % Bit No.: 3 Type: DS97+GNV Bit Size: 12 1/4 Wt On Bit: 15/20 RPM: 50 Hrs. On Bit: 49.5 Jets: 15 \ 15 \ 15 \ 15 \ 15 \ 15 TFA: 1.0350 Total Revs on Bit: Footage for Bit Run 1968' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth 9438 ft Short Trip Gas: Mud Cut: ppg Short Trip Cl: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 60 % SH 30 % SLST 10 % SD % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Depth 9060 to to Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sd Sst Sltst Sh 9140 48 100 33 375 8705 400 50 20 20 10 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Shavings and splinters 0.5 oz 24 hr Recap: Drilled from 8568' to 9115'. Circulated out gas from Kuparuk C. Drilled to 9158'. Circulated and conditioned mud due to gas. Drilled to 9329' at Midnight depth. Plan short trip at 9438' to spot Steel Seat across Schader Bluff prior to increasing mud weight for Kingak. HRZ @ 8770' MD, 8720' TVD. Base HRZ ~, 8854' MD, 8797' TVD. Kuparuk ~ 8945' MD, 8880'-FVD. Kuparuk C ~ 9060' MD, 8986' 'TVD. Max gas in Kuparuk C, 8704 units with mud wt. cut from 9.8 to 8.7 ppg: 6593 units ~ 9137' with mud cut from 9.8 to 9.2 ppg Logging Engineer: Tom Mansfield / Wayne Hermanson * 10000 units =100% Gas In Air sper n -sun Mudlogger's Morning Report Customer: BP Alaska Report No.: 16 Well: Northstar NS 31 Date: 5/10101 Area: North Slope Depth 9912' Lease: Northstar NS 31 Footage Last 24 hrs: 583' Rig: Nabors 33E Rig Activity: Drillin9 Job No.: AK AM 10142 Report For: Paul Lockwood Shows: None Current 24 hr Avg R.O.P. 80 f't/h r 71 ffJhr ( Gas* 133 units 149 unit,, ( 'Temp Out Deg F ( 97 24 hr Max Pump and Flow Data fi/hr @ 9908 ) Pump 1 117 spm DH flow 439 units @ 9293 ) Pump 2 95 spm Total flow 725 ~deg F @ ) 'Pump 3 spm AV @ rsr 'Pump Pres 3350 psi AV@ DC gpm fpm fpm Mud Wt In 11.30 ppg Visc 43 secs APl flit 5.0 mi HTHP 11.6 mi Mud Wt at Max Gas ppg MudWtOut 11.30 ppg PV 15 cP YP 28 Ibs/100ft2 Gels 20 \ 30 Ibs/100ft2 pH 8.3 Sd 0.25 % ,,, Bit No.' 3 Type: DS97+GNV Bit Size: 12 1/4 Jets: 15 \ 15 \ 15 \ 15 \ 15 \ 15 TFA: 1.0350 Wt On Bit: 15/20 RPM: 50 Hrs. On Bit: 58.5 Total Revs on Bit: Footage for Bit Run 2551' Trip Depth: ft Trip Gas: Short Trip Depth 9438 ft Shod Trip Gas: Tight Spots: to 320 to Mud Cut: ppg Trip Cl: ppm Mud Cut: ppg Short Trip Cl: ppm to Feet of Fill on Bottom: ft Current Lithology: 90 % SH 10 % SLTST % % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ~ ~ ~ __ -- ~ ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Sd Sst Sltst Sh to 10 90 to 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Shavin~ls and splinte,rs, 3.5 oz. 24 hr Recap: Drilled to 9438'. Spotted Steel Seal across Schrader Bluff. Short tripped to 7265' w/short trip ~las of.320 units. Weighted mud up to 11.3 ppg. Drilled ahead. Miluveach ~ 9310' MD. 9219' TVD. Kincjak,, ~ 9829' MD, 9709' TVD. Logging Engineer: Tom Mansfield / Wayne Hermanson * 10000 units = 100% Gas In Air Mudlogger's Morning Report Customer: BP Alaska Report No.: 17 Well: Northstar NS 31 Date: 5/11/01 Area: North Slope Depth 10618' Lease: Northstar NS 31 Footage Last 24 hrs: 706' Rig: Nabors 33E Rig Activity: Drillin9 Job No.: AK AM 10142 Report For: Paul Lockwood Shows: None Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 18 ft/hr 65 fi/hr ( 103 fi/hr @ 10275' ) Pump 1 110 spm DH flow gpm Gas* 150 units 180 unit,, ( 396 units @ 10296' ) Pump 2 107 spin Total flow 740 gpm TempOut DegF ( ~degF@ ) Pump3 spm AV@rsr fpm Pump Pres 3175 psi AY ~ DC fpm Mud Wt In 11.30 ppg Visc 41 secs APl filt 5.6 mi HTHP 11.5 mi Mud Wt at Max Gas ppg MudWtOut 11.30 ppg PV 16 cP YP 25 Ibs/100ft2 Gels 12 \ ;;3 Ibs/100ft2 pH 8.3 Sd 0.25 % Bit No.: 3 Type: DS97+GNV Bit Size: 12 1/4 Jets: 15 \ 15 \ 15 \ 15 \ 15 \ 15 TFA: 1.0350 Wt On Bit: 15/20 RPM: 50 Hrs. On Bit: 69.5 Total Revs on Bit: Footage for Bit Run 3257' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth 10406' ft Short Trip Gas: none Mud Cut: ppg Short Trip Cl: ppm Tight Spots: to ~ to to ~ Feet of Fill on Bottom: , ft Current Lithology: 70 % SH 30 % SLST % % %LCM Connection Gas and Mud Cut ~ ft __ units __ ppg ~ ft __ units __ ppg ~ ft __ units __ ppg ~ ft __ units __ ppg ~ ft __ units __ ppg ft __ units __ ppg ft ~ units , ppg ft __ units __ ppg ~ ft __ units __ ppg Depth to Drilling Breaks ) Drill Rate Gas % Lithology before during after before during after Sd Sst Sltst Sh 10 90 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Shavings and splinters, 5.0 oz. 24 hr Recap: Drilled to 10406'. Pulled one stand and replaced swabs and liners on pump #2. Pulled one stand to 10265', recipricate and circulate backreamin~l. Pulled one stand to 10177', recipricate and circulate backreamin~l. Chancged out liners on pump #1. Backream to 9347'. Run in hole. Drilled from 10406' to 10612'. ROP decreased from 70'/hr av~]. to 18' / hr. (possible bit ballincj). Pumped two nut plucg sweeps. Drillincj ahead. * 10000 units =100% Gas In Air Logging Engineer: Tom Mansfield / Doucj Wilson .... Mudlogger's Morning Report Customer: BP Alaska Report No.: 18 Well: Northstar NS 31 Date: 5/12/01 Area: North Slope Depth 10945' Lease: Northstar NS 31 Footage Last 24 hfs: 327' Rig: Nabors 33E Rig Activity: Short Trip Job No.: AK AM 10142 Report For: Paul Lockwood Shows: Sa~l River Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 18 fi/hr 22 fi/hr ( 37 fi/hr @ 10913' ) Pump 1 110 spm DH flow gpm Gas* 265 units 198 unit,,( 1206 units @ 10922' ) Pump 2 107 spm Total flow 740 gpm Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ rsr fpm Pump Pres 3175 psi AV@ DC fpm: Mud Wt In 11.30 ppg Visc 45 secs APl flit 4.8 mi HTHP 10.6 mi Mud Wt at Max Gas ppg MudWtOut 11.30 ppg PV 17 cP YP 28 Ibs/100ft2 Gels 14 \ 21 Ibs/100ft2 pH 8.0 Sd 0.25 % Bit No.: 3 Type: DS97+GNV Bit Size: 12 1/4 Jets: 15 \ 15 \ 15 \ 15 \ 15 \ 15 TFA: 1.0350 Wt On Bit: 15/20 RPM: 50 Hrs. On Bit: 84.9 Total Revs on Bit: Footage for Bit Run 3584' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip Cl: ppm Short Trip Depth 10945 ft Short Trip Gas: 164 Mud Cut: ppg Short Trip Ch ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 50 % SST 30 % SLTST 20 % SH % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Depth 10888 to 10898 10909 to 10938 before 23 20 Drilling Breaks Drill Rate Gas % Lithology during after before during after Sd Sst Sltst Sh 27 20 200 345 200 40 40 20 37 20' 200 1208 190 50 30 20 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Shavin~ls and splinters, 1.0 oz. 24 hr Recap: Drilled to 10826'. Worked on pumps. Drilled ahead to 10945', T.D. for intermediate casin¢ out. Short tripped to 8590'. Ran to bottom. Short trip ~las 164 units. Preparin9 to spot Steel Seal pill across Schrader 8luff and POOH. Sa~l River (~ 10868' MD, 10717' TVD Logging Engineer: Tom Mansfield /Dou9 Wilson * 10000 units =100% Gas In Air Mudlogger's Morning Report Customer: BP Alaska Report No.: 19 Well: Northstar NS 3'I Date: 5/13/01 Area: North Slope Depth 10945' Lease: Northstar NS 31 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: Run 9 5/8" CSG Job No.: AK AM 1014:2 Report For: Paul Lockwood Shows: Current :24 hr Avg 24 hr Max Pump and Flow Data R.O.P. fi/hr fi/hr ( ~ fi/hr @ ) Pump 1 spm DH flow gpm Gas* units unit., ( ~ units @ ) Pump 2 spm Total flow gpm TempOut DegF ( ~degF@ ) Pump3 spm AV@rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 11.30 ppg Visc 45 secs APl flit 4.8 mi HTHP 10.6 mi Mud Wt at Max Gas ppg Mud Wt Out 11.30 ppg PV 17 cP YP 28 Ibs/100ft2 Gels 14 \ 21 Ibs/100ft2 pH 8.0 Sd 0.25 % Bit No.: 3 Type: DS97+GNV Bit Size: 12 1/4 Wt On Bit: 15/20 RPM: 50 Hrs. On Bit: 84.9 Jets: 15 \ 15 \ 15 \ 15 \ 15 \ 15 TFA: 1.0350 Total Revs on Bit: Footage for Bit Run 3584' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Shod Trip Depth ft Shod Trip Gas: Mud Cut: ppg Shod Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 50 % SST 30 % SLTST 20 % SH % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Depth to Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sd Sst Sltst Sh 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: OZ. 24 hr Recap: Spot Steel Seal pill across Schrader Bluff and POOH. L/D BHA. Run 9 5/8" Casin~l. Logging Engineer: Tom Mansfield / Douc. I Wilson * 10000 units = 100% GaS In Air' Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska Northstar NS 31 North Slope Northstar NS 31 Nabors 33E AK AM 10142 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 20 5/14/01 10945' 0 Run 9 5/8" CSG Paul Lockwood Current 24 hr Avg :R.O.P. ft/hr f't/h r ( Gas* units unit,,( Temp Out De9 F ( 24 hr Max fi/hr @ units @ deg F @ Pump and Flow Data ) Pump 1 spm DH flow ) Pump 2 spm Total flow ) ~Pump 3 spm AV @ rsr Pump Pres psi AV @ DC gpm gpm fpm fpm Mud Wt In 11.30 ppg Visc 43 secs MudWtOut 11.30 ppg PV 16 cP YP APl flit 5.1 24 Ibs/100ft2 ,,, mi HTHP 11.0 mi Mud Wt at Max Gas Gels 13 \ 20 Ibs/100ft2 pH 8.0 PPg Sd 0.25 % Bit No.: Type: Bit Size: Wt On Bit: RPM: Hrs. On Bit: Jets: \ \ \ \ \ TFA: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to Mud Cut: ppg Trip CI: Mud Cut: ppg Short Trip CI: to Feet of Fill on Bottom: ppm ppm ft Current Lithology: 50 % SST 30 % SLTST 20 % SH %LCM Connection Gas and Mud Cut ~ ft __ units __ ppg ,,. ft units __ ppg ~ ff_ units __ ppg ff __ units __ ppg ~ ff __ units ppg ff __ units .-- ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas before during after before during after Sd % Lithology Sst Sltst Sh 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. 24 hr Recap: Ri9 up and run 9-5/8 casing to approximately 35' from bottom- noted displaced returns until hanger and landing joint. Worked pipe in an attempt to circulate; casincj packed off. Rig down casing !ools & p/u cement head and work pipe (stagin~ pressure from 500 psi to 3000 psi) no circulation gradually worked pipe until casincg landed. Currently packed off with no returns - in the process of rigging up wireline. !Logging Engineer: Tom Mansfield / Dou~] Wilson 10000 units = 100% Gas In Air spenn -sun Mudlogger's Morning Report Customer: BP Alaska Report No.: 21 Well: Northstar NS 31 Date: 5/15/01 Area: North Slope Depth 10945' Lease: Northstar NS 31 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: Perf. Casing Job No.: AK AM 10142 Report For: Paul Lockwood Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr fi/hr ( ~fi/hr @ ) Pump 1 spm DH flow gpm Gas* units unit,, ( ~ units @ ) Pump 2 spm Total flow gpm TempOut DegF ( ~degF@ ) Pump3 spm AV@rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 10.10 ppg Visc 40 secs APl flit 6.5 mi HTHP 12.2 mi Mud Wt at Max Gas ppg MudWtOut 10.10 ppg PV 13 cP YP 19 Ibs/100ft2 Gels 9 \ 18 Ibs/100ft2 pH 7.5 Sd 0.2 % Bit No.: Type: Bit Size: Jets: \ \ \ \ \ TFA: Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut: ~PPg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 50 % SST 30 % SLTST 20 % SH % %LCM Connection Gas and Mud Cut ~ft units ~ ppg ft __ units , ppg ft units ppg ~ft __ units ~ ppg ft units ~PPg ft units ppg ~ft __ units ~ ppg ft __ units ppg ft __ units ~ ppg Depth before Drilling Breaks Drill Rate Gas % Lithology during after before during after Sd Sst Sltst Sh 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: OZ. 24 hr Recap: Run wireline logs, R/D and elevate usit & prepare for running perforation guns. P/U perf-¢uns and RIH ( Fired 9uns at approx. 10' above float collar as of 0200 5/16 ) Logging Engineer: Tom Mansfield /Doug Wilson * 10000 units =100% Gas In Air Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 31 Area: North Slope Lease: Northstar NS 31 Rig: Nabors 33E Job No.: AK AM 10142 Report No.: 22 Date: 5/16/01 Depth 10945' Footage Last 24 hrs: 0 Rig Activity: W©C Report For: Paul Lockwood Shows: Current 24 hr Avg 24 hr Max R.O.P. ft/hr ft/hr ( ft/hr @ Gas* units unit.~ ( units @ Temp Out Deg F ( deg F @ 1200 Pump and Flow Data Pump 1 spm DH flow gprr Pump 2 spm Total flow gpm Pump 3 spm AV @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.30 ppg Visc 42 secs APl flit 3.4 mi HTHP 9.6 mi Mud Wt at Max Gas ppg Mud Wt Out 9.30 ppg PV 13 cP YP 26 Ibs/100ft2 Gels 8 \ 11 lbs/100ft2 pH 9.0 Sd 0 % Bit No.: Type: Bit Size: Jets: \ \ \ \ \ TFA: Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: 1200 Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithoiogy: 50 % SST 30 % SLTST 20 % SH % %LCM Connection Gas and Mud Cut ~ft __ units ~PPg ft units ppg ft units __PPg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Depth before Drilling Breaks Drill Rate Gas % Lithology during after before during after Sd Sst Sltst Sh 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: OZ. 24 hr Recap: R/U cement head and circulate w/max of 1200 units Pump cement down hole and displace mud taking] returns via draWl-chain ( Approx. 6 hrs, ) Currently cleanin~l L-PIT 1&2. and trip tank. ( Waitin~l on cement - 8 hrs.) Logging Engineer: Tom Mansfield / Dou~l Wilson * 10000 units = 100% Gas In Air BFilLL. I 1~i El BER~/I I-- E 5 _. Mudlogger's Morning Report Customer: BP Alaska Report No.: 23 Well: Northstar NS 31 Date: 5/17/01 Area: North Slope Depth 10945' Lease: Northstar NS 31 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: Job No.: AK AM 10142 Report For: Paul Lockwood Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. f'dhr ft/hr ( ~ft/hr @ ) Pump 1 spm DH flow gpm Gas* units unit,' ( units @ 1200 ) Pump 2 spm Total flow gpm Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.30 ppg Visc 42 secs APl flit 3.4 mi HTHP 9.6 mi Mud Wt at Max Gas ppg Mud WtOut 9.30 ppg PV 13 cP YP 26 Ibs/100ft2 Gels 8 \ 11 Ibs/100ft2 pH 9.0 Sd 0 % Bit No.: Type: Bit Size: Jets: \ \ \ \ \ TFA: Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: 1200 Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 50 % SST 30 % SLTST 20 % SH % %LCM Connection Gas and Mud Cut ft ~ units ~ ppg ~ ft __ units ~ ppg ft __ units ~PPg ft __ units ~ ppg ~ ft __ units ppg ~ ft __ units ~ ppg ft units ppg ft units ppg ft units ppg Depth to Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sd Sst Sltst Sh 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: OZ. 24 hr Recap: WOC- set emergency slips- clean pits and mud up Dril-n-fluid- currently TIH with DP to taxi top of cement- plan to LD this drill string. , Logging Engineer: Tom Mansfield/,Doug Wilson 10000 units =100% Gas ln Air Mudlogger's Morning Report Customer: BP ALaska Report No.: 24 Well: Northstar NS 31 Date: 5/18/01 Area: North Slope Depth 10945' Lease: Northstar NS 31 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: Test BOP's Job No.: AK AM 10142 Report For: Paul Lockwood Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr fi/hr ( ~ fi/hr @ ) Pump 1 spm DH flow gpm Gas* units unit., ( units @ 1200 ) Pump 2 spm Total flow gpm TempOut DegF ( ~degF@ ) Pump3 spm AV@rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.30 ppg Visc 39 secs APl flit 5.1 mi HTHP 9.9 mi Mud Wt at Max Gas ppg MudWtOut 9.30 ppg PV 11 cP YP 20 Ibs/100ft2 Gels 8 \ 10 Ibs/100ft2 pH 8.8 Sd 0 % Bit No.: Type: Bit Size: Jets: \ \ \ \ \ TFA: Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut: ppg Trip Cl: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: tO to to Feet of Fill on Bottom: ft Current Lithology: 50 % SST 30 % SLTST 20 % SH % %LCM Connection Gas and Mud Cut ... ff units __ppg . fi__units __ppg fi__units __ppg ff units ppg ft units ppg ft units ppg ~ ft units ppg ft __ units ppg ft units ppg Depth before Drilling Breaks Drill Rate Gas % Lithology during after before during after Sd Sst Sltst Sh 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: OZ. 24 hr Recap: RIH to 10000' - Test choke -la,)/down 5" drill pipe - Drain BOP stack, pull wear ring - perform freeze protect between 9 5/8 and 13 3/8 using 108 BBLS diesel and 4 BBLS escaid - make up test plug - test BOP'S Logging Engineer: Tom Mansfield / Doucj Wilson * 10000 units =100% Gas In Air Mudlogger's Morning Report Customer: BP Alaska Report No.: :25 Well: Northstar NS 31 Date: 5/19/01 Area: North Slope Depth 10945' Lease: Northstar NS 31 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: RIH,DRL CMT Job No.: AK AM 1014:2 Report For: Paul Lockwood Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 55 CMT fi/hr fi/hr ( ~ fi/hr @ ) Pump 1 88 spm DH flow gpm Gas* 15 units unit,, ( ~ units @ ) Pump 2 88 spin Total flow 620 gpm TempOut DegF ( ~degF@ ) Pump3 spm AV@rsr fpm Pump Pres 1200 psi AV @ DC fpm Mud Wt In 9.30 ppg Visc 40 secs APl flit 4.9 mi HTHP 9.8 mi Mud Wt at Max Gas ppg MudWtOut 9.30 ppg PV 11 cP YP 20 Ibs/100ft2 Gels 8 \ 11 Ibs/100ft2 pH 8.7 Sd 0 % Bit No.: 5 Type: 20MFDPS Bit Size: 8 1/2 Jets: 28 \ 28 \ 28 \ \ \ TFA: 1.8050 Wt On Bit: 15.00 RPM: 65 Hrs. On Bit: Total Revs on Bit: Footage for Bit Run Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Fe~t of Fill on Bottom: ft Current Lithology: 50 % SST 30 % SLTST 20 % SH % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ,, , ~ ft __ units __ ppg ft __ units ~ ppg ft __ units . ppg ~ft units ppg ft units ~PPg ft units ~PPg Depth to before Drilling Breaks Drill Rate Gas % Lithology during after before during after Sd Sst Sltst Sh 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: OZ.. 24 hr Recap: Finished testing BOP'S. Pick up 5" Drill pipe - RIH to drill cement. Tag cement at 10486'. Logging Engineer: Tom Mansfield / Douc. I Wilson * 10000 units =100% Gas ln Air , Mudlogger's Morning Report Customer: BP Alaska Report No.: 26 Well: Northstar NS 31 Date: 5/20/0'1 Area: North Slope Depth 11110 Lease: Northstar NS 31 Footage Last 24 hrs: 165 Rig: Nabors 33E Rig Activity: DRILLING Job No.: AK AM 10142 Report For: Paul Lockwood Shows: YES Current R,O.P. 65 ft/hr Gas* 100 units Temp Out 120 Deg F 24 hr Avg 24 hr Max Pump and Flow Data 19 fi/hr( 119 fi/hr @ 11085 ) Pump1 76 spm DH flow gpm 170 unit,'( 895 units @ 11079 ) Pump 2 75 spm Total flow 516 gpm ( degF@ ) Pump3 spin AV~rsr fpm Pump Pres 790 psi AV@ DC fpm Mud Wt In Mud Wt Out 9.30 ppg Visc 43 secs APl flit 4.9 mi HTHP 9.9 mi Mud Wt at Max Gas ~PPg 9.30 ppg PV 8 cP YP 20 Ibs/100ft2 Gels 7 \ 10 Ibs/100ft2 pH 8.0 Sd 0.1 % Bit No.: 5 Wt On Bit: 35 - 40 Type: 20MFDPS Bit Size: 8 1/2 Jets: 2,8 \ 28 \ 28 \ __\ __\ __TFA: 1.8050 RPM: 90 Hrs. On Bit: 8.2 Total Revs on Bit: Footage for Bit Run 165 Trip Depth: Shod Trip Depth Tight Spots: ft Trip Gas: Mud Cut: ~PPg Trip Cl: ppm ft Shod Trip Gas: Mud Cut: ...... ppg Short Trip Cl: ppm to to to Feet of Fill on Bottom: ft Current Lithology: ft units 'ft units ft units 40 % SST 30 % CONGL 10 % SH 20 % LS %LCM Connection Gas and Mud Cut ~ ppg ~ ft __ units ~ ppg ~ ft __ units ,., ppg ~ ppg ~ ft ~ units ~ ppg ft ~ units __..._- ppg , ,. ppg ff __ units ~ ppg ft __ units __.._-. ppg Depth 11068 to na to Drilling Breaks Drill Rate Gas % Litholog¥ before during after before during after Cgl Sst Ls Sh 25 119 na 100 895 na 30 40 10 20 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: SPLITTERS, NO SHAVINGS 0,5 oz. 24 hr Recap: Drilled out cement and 20' new hole. FIT. Circ and clean hole. Clean L pits and pit 1. Monitor hole. Displace old KCL Polymer with DRILL-N-FLUID. Drill ahead. Tops: Shub,lik ~ 10978' MD, 10825' TVD Ivishak ~ 11068' MD, 10913' TVD * 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield f Doucj Wilson Mudlogger's Morning Report Customer: BP Alaska Report No.: 27 Well: Northstar NS 31 Date: 5/21/01 Area: North Slope Depth 11440 T. D. Lease: Northstar NS 31 Footage Last 24 hfs: 330 Rig: Nabors 33E Rig Activity: WIPER TRIP Job No.: AK AM 10142 Report For: Paul Lockwood Shows: Ivishak Current 24 hr Avg 24 hr Max Pump and Flow Data R,O.P. fi/hr 16.3 fi/hr ( 103 fi/hr @ 11112 ) Pump 1 spm DH flow gpm Gas* units 98 unit,,( 498 units @ 111,37 ) Pump 2 spm Total flow gpm Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.30 ppg Visc 44 secs APl flit 4.3 mi HTHP 9.8 mi Mud Wt at Max Gas ~.PPg Mud Wt Out 9.30 ppg PV 9 cP YP 27 Ibs/100ft2 Gels 11 \ 17 Ibs/100ft2 pH 8.4 Sd 0.2 % Bit No.: 5 Type: 20MFDPS Bit Size: 8 1/2 Wt On Bit: 35 - 40 RPM: 95 Hrs. On Bit: 28.5 Jets: 28 \ 28 \ 28 \ \ \ TFA: 1.8050 Total Revs on Bit: Footage for Bit Run 495 Trip Depth: ft Trip Gas: Short Trip Depth 11440 ft Short Trip Gas: Tight Spots: to ,, , to Current Lithology: 100 % SHALE % 141 units Mud Cut: ppg Trip CI: ppm Mud Cut: ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft % . % %LCM Connection Gas and Mud Cut ft __ units ~ ppg ~ ft __ units ~ ppg ft __ units -._-_-_ ppg ~ ft __ units ~ ppg ft units ppg ft units ~ ppg ft units ppg ~ ft __ units _..._._.ppg ff __ units .----.- ppg Drilling Breaks Depth Drill Rate Gas before during after before during after Cgl 11068 to 11210 25 119 28 100 895 100 50 11250 to 11310 30 63 9 95 262 80 -"i(J" %' Lithology Sst Ls Sh 50 90' ,, 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: SPLITTERS, NO SHAVINGS 0.5 oz. 24 hr Recap: Drilled ahead to T.D. of 11440'. Monitored well, O.K. Wiper tripped to shoe. Monitored well, O.K, Ran back to bottom and circulated out with short trip gas of 141 units. Continued circulating 1/2 bottoms up. POOH for wireline Io~]s. TOPS: Kavik..~, 11383' MD, 11226' TVD Logging Engineer: Tom Mansfield / Dou~l Wilson * 10000 units = 100% Gas In Air Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska Northstar NS 31 North Slope Northstar NS 31 Nabors 33E AK AM 10142 Report No.: Date: Depth Footage Last 24 hrs.' Rig Activity: Report For: Shows: 28 5/22/01 11440 T.D. E-Log Paul Lockwood Current 24 hr Avg R.O.P. ft/hr fi/hr ( Gas* units unit,, ( Temp Out Deg F ( 24 hr Max fi/hr @ units @ deg F @ Pump and Flow Data ) Pump 1 spm DH flow ) Pump 2 spm Total flow ) Pump 3 spm AV @ rsr Pump Pres psi AV @ DC gpm gpm fpm fpm Mud Wt In 9.30 ppg Visc Mud Wt Out 9.30 ppg PV 41 secs 7 cP YP APl flit 4.5 20 Ibs/100ft2 , , mi HTHP 10.0 mi Mud Wt at Max Gas Gels 10 \ 16 Ibs/100ft2 pH 8.2 Sd PPg TR Bit No.: Type: Wt On Bit: RPM: Bit Size: Hrs. On Bit: Jets: \ \ \ \ \ TFA: Total Revs on Bit: Footage for Bit Run Trip Depth: Shod Trip Depth Tight Spots: to ft Trip Gas: ft Shod Trip Gas: to Mud Cut: ppg Trip CI: Mud Cut: ppg Shod Trip CI: to. Feet of Fill on Bottom: ppm ppm ft Current Lithology: % , , ~ % % % %LCM ft units ppg ft units ppg ft units ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units .__---- ppg Depth Drill Rate before during to Drilling Breaks Gas after before during % Lithology after Cgl Sst Ls Sh 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. 24 hr Recap: Pull out of hole. E-Log. * 10000 units: 100% Gas In A'i'r . Logging Engineer: Tom Mansfield / Dou~l Wilson Schlumberger # Job # 40006220 Date In 26-Apr-01 Date Out 27-Apr-01 Hole Size 16 Customer BP ADW Time In 7:00 Time Out 2:30 Hole Sect Surface Well NS31 Depth In 199 Depth Out 231 Bha Type Clean out Field Northstar TVD in 199 TVD Out 231 Hrs BRT 19.5 Rig Nabors 33E Drlg Hrs 0.3 Drlg Ft 32 Avg ROP 107 AFE # 831305 Slide Hrs 0.0 Slide Ft 0 Slide ROP 0 DD's Levad / Rinke Rot Hrs 0.3 Rot Ft 32 Rot ROP 107 Co. Men Polya / Dinger Pump Hrs 2.0 Rotate % 100 Slide % 0 PDM Run # n/a P,/S PDM Jet Incl In 0.00 Az In 0.00 Bit>Svy N/A PDM Ser# Stages Bearing incl Out 0.40 Az Out 22.30 T/F Corr N/A PDM Size Rev/Gal Rubber Avg Dis 0.1 Max Dis 0.4 Plan Dis 0.0 Mud Type SeaH20 Spud Mud Wt 9.4 Sand % tr RPM 60 GPM 700 SPP On: 450 BHT F N/A Mud Vis 128 Solids % 8 Rot TQ 2k WOB 5 SPP Off: 450 Item Description Vendor S/N OD ID Stab OD F.N. Connection. Length Cum Length Bit#1 MX-C1 1 TFA 1.224 HTC R89DW 16 1-12,3x22 7 5/8 Reg P 1.35 1.35; X-OVER 7 5/8 Reg B 2 Ana GLDD-425 ~ 1/16X9 1/1( 2 7/8 On rig floo, 1.07 6 5/8 Reg P 2.20 3.55 BIT SUB 6 5/8 Reg B 3 *Totco ring / *Float Ana GLDD-120 7 7/8 2 15/16 On rig floo, 6 5/8 H90 B 2.93 6.48 MONEL STAB 6 5/8 H-90 P 4 Ana 800-011-SB 8 2 7/8 16 2.40 6 5/8 H-90 B 5.62 12.10 , MONEL DC 6 5/8 H-90 P 5 Ana 831-o21 DC 8 1/16 2 13/16 6 5/8 H-90 B 30.94 43.04 MONEL DC 6 5/8 H-90 P 6 Ana 831-002DC 7 15/16 2 7/8 6 5/8 H-90 B 30.74 73.78 MONEL STAB 6 5/8 H-90 P 7 Ana 800-010-SB 8 2 7/8 16 2.40 6 5/8 H-90 B 5.63 79.41 MONEL DC 6 5/8 H-90 P 8 *Corrosion Ring Ana 831-019DC 8 1/8 2 13/16 6 5/8 H-90 B 30.85 1 10.26 HYD JAR 6 5/8 H-90 P 9 Dailey 1417-1121 7 3/4 3 1.70 4 1/2 IF a 30.98 141.24 29 Jts. HWDP 5" 4 1/2 IF P 10 NAD 29 HWDP 5 3 4 1/2 IF B 879.07 1020.31 DP 5" to Surface 4 1/2 IF P 11 NAD DP 5 4 8/29 4 1/2 IF B 1020.31 ,,, , , ~HA Expected Behavior: Clean out 20" conductor. Gyro survey conductor. Bit Data Tool Hrs. In ' Hrs. Out , Expect conductor to be straight hole IADC # 115 Motor 2.0 BHA Actual Behavior: las expected Footage 32 Jars 99.0 9.9.3 Hrs 0.3 Bit #1 0.0 0.3 ~omments /Reason for Trip: I Good run. Gyro ru'n good. POOH to P/U motor, MWD. k Revs 1 k ;2.0 Grade Green '~omment Schlumberger # Job # 40006220 Date In 27-Apr-01 Date Out 29-Apr-01 Hole Size i6 Customer BP ADW Time In 7:30 Time Out 7:00 Hole Sect Surface Well 'NS31 ' ' Depth In 231 Depth Out 3249 Bha Type Steerable ._ Field Northstar TVD In 231 TVD Out 3245 Hrs BRT 47.5 Rig Nabors 33E Drlg Hrs 18.7 Drlg Ft 3018 Avg ROP 161 AFE # 831305 Slide Hrs 3.1 Slide Ft 402 Slide ROP 130 ,,. DD's Levad/Rinke Rot Hrs 15.6 Rot Ft 2616 Rot ROP 168 .. Co. Men Polya / Dinger Pump Hrs 32.4 Rotate % 87 Slide % 13 PDM Run # 1 R/S 3/4 PDM Jet Blk Inci ln 0.40 Az in 22.30 Bit>Svy 68.55 PDM SerI¢ 962-1017 Stages 4.5 Bearing Mud Incl Out 0.17 Az Out 91.24 T/F Corr 171.3 PDM Size 9 5/8 Rev/Gal 0.220 Rubber RM100D Avg Dis Max Dis Plan Dis 1.0 ,., Mud Type SeaH20 Spud Mud Wt 9.6 Sand % 2.0 RPM 50 GPM 700 SPP On: 1350 BHT F Mud Vis 150 Solids % 9.0 Rot TQ 5K WOB 20 SPP Off: 1600 Item Description Vendor SiN OD ID Stab OD F.N. Connection Length Cum Length ,, Bit#1 MX-C1 1 TFA 1.224 HTC R89DW 16 1-12,3x22 7 5/8 Reg P 1.35 1.35, 9 5/8 Std PDM 1.83 7 5/8 Reg B 2 *Float Ana 962-1017 9 5/8 Tool 15 7/8 16.75 6 5/8 H-90 B 26.65 28.00 MONEL LC 6 5/8 H-90 P 3 Ana 810-003-LC 8 2 7/8 6 5/8 H-90 B 9.72 37.72 MONEL LC 6 5/8 H-90 P 4 Ana 8-10-001-LC 8 1/16 2 13/16 6 5/8 H-90 B 10.45 48.17 MONEL STAB 6 5/8 H-90 P 5 Aha 800-007-SB 8 2 7/8 16 2.39 6 5/8 H-90 B 5.62 53.79 MWD 6 5/8 FH P 6 Aha MDC-196 8 3/8 Tool 2.00 6 5/8 Hg0 B 31.08 84.87 Orienting Sub 6 5/8 H-90 P 7 *Mule Shoe Ana GLDD-878 8 2 1/2 3n dg floo 6 5/8 H-90 B 1.66 86.53 MONEL STAB 6 5/8 H-90 P 8 Ana 800-011-SB 8 2 7/8 16 2.40 6 5/8 H-90 B 5.62 92.15 MONEL DC 6 5/8 H-90 P 9 Ana 831-021DC 8 1/16 2 13/16 6 5/8 H-90 B 30.94 123.09 MONEL DC 6 5/8 H-90 P 10 Ana 831-002DC 7 15/16 2 7/8 6 5/8 H-90 B 30.74 153.83 MONEL STAB 6 5/8 H-90 P 11 Ana 800-010-SB 8 2 7/8 16 2.40 6 5/8 H-90 B 5.63 159.46 MONEL DC 6 5/8 H-90 P 12 *Corrosion Ring Ana 831-019DC 8 1/8 2 13/16 6 5/8 H-90 B 30.85 190.31 , , HYD JAR 6 5/8 H-90 P 13 Dailey 1417-1121 7 3/4 3 1.70 4 1/2 IF B 30.98 221.29 "' 29 Jts. HwDP 5" 4 1/2 IF P 14 NAD 29 HWDP 5 3 4 1/2 IF B 879.07 1100.36 DP 5" to Surface 4 1/2 IF P 15 NAD DP 5 4 8/29 4 1/2 IF B 1100.36 BHA Expected Behavior: Expect 4-6/100' DLS sliding, hold rotating. Bit Data Tool Hrs. In Hrs. Out IADC # 115 Motor 51.7 84.1 BHA Actual Behavior: las expected Footage 3018 Jars 99,3 118,0 Hrs 18.7 Bit #1 0.3 19.0 C~mments / Reasoll for Trip: " ' , IGood run. POOH for 13 3/8" casing point, k Revs 220 k , 32.4 Grade 1-2-WT.A-E-I-PN-TD Bi't' to: D&1=68.55, GR=66.56 2omment Schlumberger BHA # 3 Job # 40006220 Date In 01-May-01 Date Out 05-May-01 Hole Size 12 1/4 Customer BP ADW Time In 11:30 Time Out 12:00 Hole Sect intermediate Well NS31 Depth In 3249 Depth Out 6955 Bha Type Steerable Field Northstar TVD in 3245 TVD Out 6951 Hrs BRT 96.5 Rig Nabors 33E Drlg Hrs 37.0 Drlg Ft 3706 Avg ROP 100 AFE # '~"~1305 Slide Hrs 0.0 Slide Ft 0 Slide ROP 0 , i DD's Levad / Rinke Rot Hrs 37.0 Rot Ft 3706 Rot ROP 100 ] Co. Men Polya / Dinger Pump Hrs 62.0 Rotate % 100 Slide % 0 PDM Run # 2 R/S 5/6 PDM Jet BIk Incl ln 0.17 Az ln 91.24 Bit>Svy 69.81 PDM Ser# 962-1049 Stages 3.0 Bearing Mud Incl Out 0.40 Az Out 280.25 T/F Corr PDM Size 9 5/8 Rev/Gal 0.110 Rubber RM100D Avg DIs 0.1 Max DIs 0.4 Plan Dis 0.0 Mud Type KCL-Polymer Mud Wt 9.3 Sand % 0.3 RPM 80 GPM 750 SPP On: 1650 BHT F Mud Vis 45 Solids % 4.2 Rot TQ 6.5 kftlbs WOB 30-43 SPP Off: 1450 Item Description Vendor SIN OD · ID Stab OD F.N. Connection Length' Cum Length Bit#2 MX-C1 DX 1 TFA 1.006 HTC F58DH 12 1/4 2x16,2x20 6 5/8 Reg P 1.00 1.00 9 5/8 Std PDM 1.15 6 5/8 Reg B 2 *Float Ana 962-1049 9 5/8 Tool 12 1/8 16.29 6 518 H-90 B 26.98 27.98 MONEL STAB 6 5/8 H-90 P 3 Ana 800-013-SB 8 2 7/8 12 1/16 2.45 6 5/8 H-90 B 5.44 33.42 CDR (PWD) 6 5/8 Hg0 P 4 Ana 8039 8 3/16 Tool 15.13 6 5/8 FH B 22.77 56.19 MwD 6 5/8 FH P 5 Ana MDC 196 8 3/8 Tool 2.00 6 5/8 H90 B 27.23 83.42 MONEL STAB 6 5/8 H-90 P 6 *Totco Ring Ana 800-002-SB 8 2 7/8 12 1/8 2.40 6 5/8 H-90 B 5.55 88.97 MONEL DC 6 5/8 H-90 P 7 Ana 831-021DC 8 1/16 2 13/16 65/8H-90B 30.94 119.91 MONEL DC 6 5/8 H-90 P 8 Ana 831-002DC 7 15/16 2 7/8 6 5/8 H-90 B 30.74 150.65 MONEL STAB 6 5/8 H-90 P 9 Ana 800-017-SB 8 2 7/8 12 1/8 2.40 6 5/8 H-90 B 5.49 156.14 MONEL DC 6 5/8 H-90 P 10 *Corrosion dng Ana 831-019DC 8 1/8 2 13/16 6 5/8 H-90 B 30.85 186.99 , HYD JAR 6 5/8 H-90 P 11 Dailey 1417-1121 7 3/4 3 1.70 4 1/2 IF B 30.98 217.97 29 Jts. HWDP 5" 4 1/2 IF P 12 NAD 29 HWDP 5 3 4 1/2 IF B 879.07 1097.04 DP 5" to Surface 4 1/2 IF P 13 NAD DP 5 4 8/29 4 1/2 IF B 1097.04 , ,,, !BHA Expected Behavior: Expect 4-6/100' DLS sliding, hold rotating. Bit Data Tool.. Hrs. In Hrs. Out IADC # 115 Motor 48.3 110.3 '~HA.... Actual Behavior:, I No sliding nessasary. Ddlled to 6955' rotating. ' Footage 3706 Jars 118,0 155.0 Hrs 37.0 Bit #2 37.0 ;Comments/Reason for Trip: IPick up PDC, Motor, Isonic, AND tools k Revs 361 k 62.0 :R©P slowed down. Grade 6-5-WT-A-E-1/16-FC-ROP Bit to: D&1=69.81, MWD-GR=67.82, CDR-GR=50.53, PWD=41,28 Comment Schlumberger # 4 Job # 40006220 Date In 05-May-01 Date Out 07-May-01 Hole Size 12 1/4 Customer BP ADW Time In 10:30 Time Out 2:00 Hole Sect intermediate Well NS31 Depth In 6955 Depth Out 7358 Bha Type Steerable Field Northstar TVD In 6951 TVD Out 7354 Hrs BRT 39.5 Rig Nabors 33E Drlg Hrs 5.8 Drlg Ft 403 Avg ROP 69 AFE # 831305 Slide Hrs 0.0 Slide Ft 0 Slide ROP 0 DD's Tunnell / Rinke Rot Hrs 5.8 Rot Ft 403 Rot ROP 69 Co. Men Polya / Christian Pump Hrs 10.3 Rotate % 100 Slide % 0 PDM Run # 2 R/S 3/4 PDM Jet BIk Incl ln 0.40 Az In 280.25 Bit>Svy 84.57 PDM Set8 800-3198 Stages 8.2 Bearing Mud Incl Out Az Out T/F Corr 34.0.0 PDM Size 8 1/4 Rev/Gal 0.375 Rubber RM100D Avg Dis Max Dis Plan Dis 2.5 Mud Type KCL Polymer Mud Wt 9.3 Sand % 0.2 RPM 50 GPM 750 SPP On: 1550 , BHT F Mud Vis 42 Solids % 3.6 Rot TQ 7 WOB 8 SPP Off: 2000 Item Description Vendor S/N OD ID Stab OD 'P.N. Connection ' Length CUm Length Bit#3 DS97+GNV 1 TFA 1.035 H¥calog 101168 12 1/4 6x15 6 5/8 Reg P 1.00 1.00 8" GT PDM 1.50 6 5/8 Reg B 2 *Float Ana 800-3198 8 1/4 Tool 12 1/8 6 5/8 H-90 B 32.00 33.00 MONEL LC 6 5/8 H-90 P 3 Ana 810-009-LC 8 2 7/8 6 5/8 H-90 B 9.74 42.74 MONEL STAB 6 5/8 H-90 P 4 Aha 800-013-SB 8 2 7/8 12 1/16 2.45 6 5/8 H-90 B 5.44 48.18 CDR (PWD) 6 5/8 H90 P 5 Ana 8039 8 3/16 Tool 15.13 6 5/8 FH B 22.77 70.95 MWD 6 5/8 FH P 6 Ana 27531 8 7/16 Tool 6 5/8 FH P 27.26 98.21 ISonic 6 5/8 FH B 7 Aha 852 8 1/4 Tool 10.00 6 5/8 Hg0 B 23.96 122.17 MONEL STAB 6 5/8 H-90 P 8 Ana 800-002-SB 8 2 7/8 12 1/8 2.40 6 5/8 H-90 B 5.55 127.72 , MONEL DC 6 5/8 H-90 P 9 Aha 831-021DC 8 1/16 2 13/16 6 5/8 H-90 B 30.94 158.66 ,, , , MONEL DC 6 5/8 H-90 P 10 *Corrosion ring Aha 831-002DC 7 15/16 2 7/8 6 5/8 H-90 B 30.74 189.40 HYD JAR 6 5/8 H-90 P 11 Dailey 14.17-1121 7 3/4 3 1.70 4 1/2 IF B 30.98 220.38 2 Jts. HWDP 5" 4. 1/2 IF P 12 NAD 2 HWDP 5 3 4 1/2 ~F B 59.90 280.28 ADN 4. 1/2 IF P 13 Ana 256 6 15/16 Tool 8 1/4 2.34 4. 1/2 ~F B 22.34 302.62 27 Jts. HwDP 5" 4 1/2 IF P 14 NAD 27 HWDP 5 3 4 1/2 ~F B 819.17 1121.79 DP 5" to Surface 4 1/2 IF P 15 NAD DP 5 4 8/29 4 1/2 IF B 1121.79 BHA Expected Behavior: Expect 4-6/100' DLS sliding, hold rotating. Bit Data Tool . Hrs. In Hrs. OUt IADC # Motor 0.0 10.4 BHA Actual BehaviOr: I Footage 403 Jars 155.0 160.8 Hrs 5.8 Bit #3 0.0 5.8 Comments / Reason for Trip: I MW D tool failed k Revs 115 k 10.3 Grade 0-0-CT-G-X-i-NO-DTF Bit :o: Res=54.29, GR=65.29, PWD=56.04, GR-MWD=82.58, D&l=84.57,Sonic=112.18, Dens=293,L Comment MWD tool failed i, Schlumberger # 6 Job # 40006220 Date In 07-May-01 Date Out 13-May-01 Hole Size 12 1/4 Customer BP ADw Time In 5:00 Time Out 20:30 Hole Sect intermediate Well NS31 Depth In 7358 Depth Out 10945 Bha Type Steerable Field Northstar TVD in 7354 TVD Out '10792 Hrs BRT 159.5 Rig Nab°rs 33E Drlg Hrs 83.1 Drlg Ft 3587 Avg ROP 43 AFE # 831305 Slide Hrs 15.4 Slide Ft 487 Slide ROP 32 DD's Tunnell / Rinke Rot Hrs 67.7 Rot Ft 3100 Rot ROP Co. Men Polya / Christian Pump Hrs 121.1 Rotate % 86 Slide % 14 ,, PDM Run # 2 R/S 3/4 PDM Jet BIk Incl ln 0.40 Az In 280.25 Bit>Svy 84.57 PDM Ser~ 800-3198 Stages 8.2 Bearing Mud Incl Out 10.41 Az Out 49.80 T/F Corr 21.8 PDM Size 8 1/4 Rev~Gal 0.375 Rubber RM100D Avg Dis 0.6 Max Dis 1.2 Plan Dis 2.5 Mud Type KCL Polymer Mud Wt 11.3 Sand % 0.3 RPM 50 GPM 760 SPP On: 2800 BHT F Mud Vis 45 Solids % 25.3 Rot TQ 9 WOB 20 SPP Off: 3500 Item Description Vendor $/N OD ID Stab oD F.N. Connection Length Cum Length Bitff-4 DS97+GNV RR #1 1 TFA 1.035 H¥calog 101168 12 1/4 6x15 8 5/8 Reg P 1.00 1.00 8" GT PDM 1.50 6 5/8 Reg B 2 *Float Ana 800-3198 8 1/4 Tool 12 1/8 6 5/8 H-90 B 32.00 33.00 MONEL LC 6 5/8 H-90 P 3 Ana 810-009-LC 8 2 7/8 6 5/8 H-90 B 9.74 42.74 MONEL STAB 6 5/8 H-90 P 4 Ana 800-013-SB 8 2 7/8 12 1/16 2.45 6 5/8 H-90 B 5.44 48.18 CDR (PWD) 6 5/8 H90 P 5 Ana 8039 8 3/16 Tool 15.13 6 5/8 FH B 22.77 70.95 , MWD 6 5/8 FH P 6 Ana MDC 196 8 3/8 Tool 2.00 6 5/8 H90 B 27.23 98.18 ISonic 6 5J8 FH B 7 Ana 852 8 1/4 Tool 10.00 6 5/8 H90 B 23.96 122.14 MONEL STAB 6 5/8 H-90 P 8 Ana 800-002-SB 8 2 7/8 12 1/8 2,40 6 5/8 H-90 B 5.55 127.69 MONEL' DC 6 5/8 H-90 P 9 Ana 831-021DC 8 1/16 2 13/16 6 5/8 H-90 B 30.94 158.63 , MONEL DC 6 5/8 H-90 P 10 *Corrosion ring Ana 831-002DC 7 15/16 2 7/8 6 5/8 H-90 B 30.74 189.37 ' HYD JAR 6 5/8 H-90 P 11 Daile¥ 1417-1121 7 3/4 3 1.70 4 1/2 IF B 30.98 220.35 2 Jts. HWDP 5" 4 1/2 IF P 12 NAD 2 HWDP 5 3 4 1/2 IF a 59.90 280.25 ADN 4 1/2 IF P 13 Ana 256 6 15/16 Tool 6 1/4 2.34 4 1/2 IF B 22.34 302.59 27 Jts. HWDP 5" 4 1/2 IF P ' ' 14 NAD 27 HWDP 5 3 4 1/2 IF B 819.17 1121.76~ DP 5" to Surface 4 1/2 IF P 15 NAD DP 5 4 8/29 4 1/2 IF B 1121.76 ..... BHA ExpeCted Behavior: Expect 4-6/100' DLS sliding, hold rotating. Bit Data Tool Hrs. In Hrs. Out IADC # Motor 10.4 131.5 BHA Actual Behavior: , I Yielded 2.5/100' DLS with 45 foot slides Footage 3587" Jars 160.8 243.9 Dropped rotating ahead an average of .6/100 Hrs 83.1 Bit ¢i3 5.8 88.9 Comments/Reason for Trip: I Reached 9 5/8 casing point .... k Revs 1,625 'k , 121.1 Grade 4-2-RO-N-X- 1/16-BU-TD Bit to: Res=54.29, GR=65.29,'PWD=56.04, GR-MWD=82.58, D&l=84.57,Sonic=112.18, Dens=293.z Comment Bit was balled up from 10611' Io Schlumberger # 6 Job # 40006220 Date In 19-May-01 Date Out 22-May-01 Hole Size 8 1/2 Customer BP ADW Time In 12:30 Time Out 9:00 Hole Sect Production Well ~S31 Depth In 10945 Depth Out 11440 Bha Type Rotary Field '~lorthstar TVD In 10792 TVD Out 11280 Hrs BRT 68.5 Rig Nabors 33E Drlg Hrs 28.1 Drlg Ft 495 Avg ROP 18 AFE # 831305 Slide Hrs 0.0 Slide Ft 0 Slide ROP 0 DD's Levad Rot Hrs 28.1 Rot Ft 495 Rot ROP 18 Co. Men 'Lockwood/Dinger Pump Hrs 45.0 Rotate % 100 Slide % 0 PDM Run # N/A R/S PDM Jet Incl In 10.41 Az In 49.80 Bit>Svy N/A PDM Serl¢ Stages Bearing Incl Out 7.85 Az Out 48.19 T/F Corr lq/,& PDM Size Rev/Gal Rubber Avg Dis 0.6 Max Dis 1.2 Plan Dis 0.0 MudType DriI-N-Fluid MudWt 9.3 Sand% 0.1 RPM 100 GPM 460 SPPOn: 1150 BHT F N/A Mud Vis 43 Solids % 3.9 Rot TQ 10 WOB 40 SPP Off: 1150 Item Descripb'on Vendor S/N .OD . ID Stab OD P.N. I Connection ' .:. Length Cum Length .... Bit#5 20MFDGPS 1 TFA=l.805 Smith MJ0685 8 1/2 3x28 4 1/2 Reg P 1.00 1.00 NB STAB [STEEL] 4 1/2 Reg B 2 *Float / Totco Ring Ana GLS 6001 6 3/16 2 7/8 8 1/2 1.85 4 1/2 XH B 4.96 5.96 MONEL LC 4 1/2 XH P 3 Aha 675-10-004LC 6 3/4 2 13/16 4 1/2XH B 10.55 16.51 STEEL STAB 4 1/2 XH P 4 Ana GLS 204 6 3/16 2 7/8 8 1/2 1.90 4 1/2 XH e 4.96 21.47 , X-OVER 4 1/2 XH P 5 Ana GLDD1001 6 7/16 2 1/2 4 1/2 H90 B 1.51 22.98 Steel DC 4 1/2 Hg0 P 6 NAD DC4 6 1/4 2 7/8 1.30 4 1/4 H90 B 30.08 53.06 , Steel DC 4 1/2 H90 P 7 NAD DC5 6 3/16 2 7/8 1.60 4 1/4 Hg0 B 30.54 83.60 Steel DC 4 1/2 Hg0 P 8 , NAD DC6 6 1/4 2 7/8 I 1.81 4 1/4 H90 B 30.75 114.35 X-OVER 4 1/2 H90 P 9 *Corrosion dng Ana GLDD025 6 1/2 2 13/16 4 1/2 IF'B 1.68 116.03 , 3 Jts HWDP 5" 4 1/2 IF P 10 NAD 3 HWDP 5 3 4 1/2 IF B 90.97 207.00 ,, , HYD JAR 4 1/2 IF P 11 Dailey 1416-1573 6 1/2 2 3/4 1.69 4 1/2 IF B 32.60 239.60 26 Jts. HWDP 5" 4 1/2 IF P 12 NAD 26 HWDP 5 3 4 1/2 iF B 788.10 1027.70 , ,,,, DP 5'" to Surface 4 1/2 IF P 13 NAD DP 5 4 8/29 4 1/2 IF B 1027.70 , ~ ,, ,,, ,,, BHA Expected Behavior: Hold. Bit Data Tool ' Hrs.'In "'Hrs. Out .... IADc # 517X Motor 45.0 ;BHA ActUal BehaviOr: ,JAverage 0.6/100' drop, no Walk. Footage 495 Jars 5.3 33.4 Hrs 28.1 28.1 'C'ornments/Reason for Trip:' IGood run. POOH for TDi k Revs 169 k ' 45.0 l[~rop' Gyrodata survey at TD, survey TD to surface. Grade 7-8-BT-A-E-I-JD-TD ....... Comment Bit too soft for interval, run 537 next time. BHA #: 1 - 6 Slide Sheet Schlumberger Client: 8PXA Field: Northstar Structure: Northstar PF Depth In: 150.00 Inclination In: 0.00 Azimuth In: 0.00 Comments: Well: NS-31 Borehole: NS31 UWl/API~: 50-029-23009-00 Directional Driller: Scott Levad Directional Driller: Job #: Depth Out: 11440.00 Inclination Out: 7.62 Azimuth Out: 48.55 Tot Distance: 11290.00 Dist Steering: 889.00 % Steer: 7.9 Dist Rotating: 10401.00 % Rot: 92.1 Total Time: 173.1 Time Steering: 18.5 % Steer: 10.7 Time Rotating: 154.6 % Rot: 89.3 [ Total ROP: 65.2 Steedncj ROP: 48.1 Rotatincj ROP: 67,3 Rot/Slid I Md From [ Md To (R/S) I (ft) I (fi) Ic°urse (ft) I Duration (hr:.min) I R 150.00 199.00 49.00 0:09 R 199.00 231.00 32.00 0:11 R 231.00 279.00 48.00 0:13 R 279.00 311.00 32,00 0:06 R 311.00 369.00 58.00 0:19 R 369.00 460.00 91.00 0:38 S 460.00 475.00 15.00 0:08 R 475.00 478.00 3,00 0:05 S 478.00 500,00 22.00 0:15 R 500,00 552.00 52.00 0:19 S 552.00 572.00 20.00 0:17 R 572.00 597,00 25.00 0:15 S 597.00 617,00 20.00 0:13 R 617.00 644.00 27,00 0:13 S 644.00 659.00 15.00 0:05 R 659.00 689.00 30.00 0:14 S 689.00 704.00 15.00 0:05 R 704.00 734.00 30.00 0:11 S 734,00 753.00 19.00 0:07 R 753.00 784.00 31.00 0:11 S 784.00 804.00 20.00 0:07 R 804.00 825.00 21.00 0:16 S 825.00 845.00 20.00 0:06 R 845.00 875.00 30.00 0:07 S 875.00 895.00 20.00 0:05 R 895.00 916.00 21.00 0:06 S 916.00 941.00 25.00 0:08 R 941.00 974.00 33.00 0:08 S 974.00 999.00 25.00 0:08 R 999.00 1008.00 9.00 0:05 S 1008,00 1033.00 25.00 0:07 R 1033.00 1097.00 64.00 0:18 R 1097.00 1191.00 94.00 0:34 S 1191.00 1216.00 25.00 0:20 R 1216.00 1287.00 71.00 0:28 S 1287.00 1313.00 26.00 0:14 P, 1313.00 1381.00 68.00 0:24 R 1381.00 1476.00 95.00 0:31 R 1476.00 1570.00 94.00 0:30 S 1570.00 1590.00 20.00 0:06 R 1590.00 1665.00 75.00 0:19 R 1665.00 1761.00 96.00 0:29 R 1761.00 1855.00 94.00 0:27 TF I AvgROPI WOB Flow ISPPOffBISPPO, BI RPM ~orqOnB1 SvyMdi D~s I (°) I (ft/h) I(1000 lb0 (gaUmin) J (psi) I (psi) I / (A) (fi) I (°) ° (°/100 ~ 0.00 0.00 0.00 -- 91.00 0,18 52.92 0,20 -- 327 5 700 450 450 60 2 182.00 0,25 49,14 0.08 -- 175 7 700 450 450 60 2 -- 222 5 700 650 700 35 2 273.00 0.25 41.21 0.04 -- 320 5 700 650 800 35 2 -- 183 3 700 700 750 35 2 364.00 0,32 54.88 0.11 -- 144 10 700 800 850 35 2 455.00 0,50 80,25 0.28 M 100 113 15 680 750 850 0 0 -- 36 10 680 750 850 45 2 M 100 88 10 680 750 850 0 0 -- 164 8 680 750 850 45 2 M90 71 12 700 950 1100 0 0 -- 100 5 700 950 1050 45 3 M 90 92 8 680 850 950 0 0 547.00 0.91 97,94 0.50 -- 125 3 680 850 900 45 3 638.00 1.42 102.98 0.57 M70 180 2 640 850 900 0 0 -- 129 5 640 850 900 45 2 M60 180 2 640 850 900 0 0 -- 164 8 640 850 950 45 2 728.00 2.39 94,90 1.12 M 85 163 10 640 950 1050 0 0 -- 169 8 640 950 1050 50 3 M85 171 10 640 950 1050 0 0 -- 79 10 640 950 1050 50 3 M 90 200 10 640 950 1050 0 0 -- 257 10 640 950 1050 45 3 M 90 240 10 640 950 1050 0 0 -- 210 10 640 950 1050 45 3 M90 188 5 640 950 1050 0 0 -- 248 5 640 950 1050 45 3 819.00 2.92 91.77 0.60 914.00 3.83 93,09 0,96 M 90 188 5 640 950 1050 0 0 -- 108 5 640 950 1050 45 3 1008.00 4.54 91,48 0,77 G 0 214 5 640 1000 1100 0 0 -- 213 5 640 1000 1100 45 3 -- 166 20 640 1000 1250 45 5 1103.00 4.97 90,97 0.45 G 25 75 15 640 1000 1100 0 0 1198.00 4.66 91,84 0.34 - 152 25 640 1000 1200 45 5 G 0 111 25 640 1000 1200 0 0 1292.00 4.72 92.34 0.08 --, 170 25 640 1000 1200 45 5 -- 184 25 640 1050 1200 45 5 1387.00 4.99 93.88 0.32 -- 188 25 640 1050 1200 45 5 1481.00 4.82 95,98 0.26 G 170 200 15 640 1050 1100 0 0 1576.00 4.36 94.12 0.51 -- 237 3 700 1200 1300 45 5 -- 199 5 700 1200 1300 45 5 1670.00 3.69 95.04 0.72 -- 209 8 700 1300 1400 45 5 1765,00 3.77 95,49 0,09 NS31\NS-31\NS31\ Page 1 of 4 5/23/2001-12:29 AM {R/S) (ft) {ft) (ft) (hr:.min) (°) (ffJh) (1000 Ibf) (galJmin) (psi) (ps) | (A) (ft) (°) (") 1("/100 ft) S 1855.00 1875.00 20.00 0:12 G-160 100 8 700 1300 1550 0 0 1860.00 3.35 92.86 0.47 R 1875.00 1905.00 30.00 0:07 -- 257 3 700 1300 1450 45 5 S 1905.00 1920.00 15.00 0:05 G-160 180 8 700 1300 1500 0 0 R 1920.00 1950.00 30.00 0:09 -- 200 3 700 1300 1400 45 5 S 1950.00 1970.00 20.00 0:06 G180 200 5 700 1300 1450 0 0 1954.00 1.69 72.62 1.98 R 1970.00 2045.00 75.00 0:24 -- 188 5 R 2045.00 2139.00 94.00 0:29 -- 194 5 R 2139.00 2233.00 94.00 0:30 -- 188 8 R 2233.00 2328.00 95.00 0:32 -- 178 8 S 2328.00 2343.00 15.00 0:11 M235 82 8 700 1300 1400 45 700 1350 1500 45 700 1400 1550 45 700 1400 1550 45 700 1400 1550 0 5 5 2049.00 0.97 56.98 0.84 5 2143.00 1.01 56,25 0.04 5 2238.00 1.07 57,65 0.07 0 2332.00 0.92 61.87 0.18 2343.00 2422.00 79.00 0:27 -- 176 2422.00 2517.00 95.00 0:35 -- 163 2517,00 2611.00 94.00 0:32 -- 176 2611.00 2705.00 94.00 0:30 -- 188 2705.00 2800.00 95.00 0:32 -- 178 20 700 1400 1700 50 20 700 1400 1700 50 15 700 1400 1550 50 25 700 1300 1650 50 25 700 1300 1600 50 5 5 2427.00 0.47 83.65 0.54 5 2522.00 0,42 85.64 0,06 6 2616.00 0.44 86,10 0.02 6 2711.00 0.41 87.92 0.03 2800.00 2894.00 94.00 0:24 -- 235 2894.00 2989,00 95,00 0:26 -- 219 2989.00 3085.00 96.00 0:42 -- 137 3085.00 3178.00 93.00 1:04 -- 87 3178,00 3249.00 71.00 0:49 -- 87 15 700 1300 1550 50 15 700 1350 1550 50 15 700 1350 1550 50 20 700 1350 1600 50 20 700 1350 1600 50 5 2805.00 0.37 89.54 0.04 5 2900.00 0.35 91.29 0.02 5 2995.00 0,37 90,10 0.02 5 3089,00 0.29 97.76 0.10 5 3184.00 0.13 102.38 0.17 R 3249,00 3272.00 23.00 0:12 -- 115 R 3272.00 3275.00 3.00 0:13 -- 14 R 3275,00 3280.00 5.00 0:27 -- 11 R 3280,00 3366.00 86.00 0:42 -- 123 R 3366,00 3460.00 94,00 0:22 -- 256 25 650 1050 1200 50 25 750 1050 1200 80 30 750 1050 1200 80 20 750 1200 1400 80 5 750 1100 1300 80 4 5 4 3278,00 0.15 91.39 0,04 5 5 3373.00 0.20 63.28 0.10 R 3460.00 3556.00 96.00 0:47 -- 123 R 3556,00 3650.00 94.00 0:52 -- 108 R 3650.00 3744.00 94.00 0:22 -- 256 R 3744.00 3839,00 95,00 0:33 -- 173 R 3839.00 3934,00 95,00 0:31 -- 184 5 750 1050 1150 80 25 750 1050 1300 80 15 750 1100 1350 80 25 750 1100 1400 80 25 750 1150 1450 80 4 3467.00 0.19 51.64 0.04 5 3562.00 0.30 52.71 0.12 5 3657.00 0.37 51.17 0.07 5 3751.00 0.45 50.48 0.09 5 3846.00 0.47 54.47 0.04 3934,00 3995.00 61.00 0:16 -- 229 3995.00 4028.00 33,00 0:11 -- 180 4028,00 4122.00 94,00 0:24 -- 235 4122.00 4216.00 94.00 0:23 -- 245 4216.00 4310,00 94.00 0:22 -- 256 8 750 1100 1250 80 15 750 1100 1250 80 25 750 1200 1400 80 10 750 1200 1350 80 15 750 1200 1350 80 5 3940.00 0.46 57,38 0,03 5 5 4035.00 0.47 57.97 0.01 5 4129.00 0.37 58.25 0.11 5 4224.00 0.38 62.98 0,03 4310.00 4405.00 95.00 0:37 -- 154 4405,00 4500.00 95.00 0:59 -- 97 4500.00 4594,00 94.00 0:53 -- 106 4594,00 4688.00 94.00 1:07 -- 84 4688.00 4783.00 95.00 0:45 -- 127 15 750 1250 80 750 1300 1500 80 30 750 1300 1550 30 750 1300 1550 80 30 750 1350 1550 80 5 4319.00 0.37 62.05 0.01 5 4413.00 0.27 85.30 0.17 5 4508.00 0,27 71.54 0.07 5 4602.00 0.19 61.26 0.10 5 4697.00 0,19 62.13 0.00 R 4783.00 4877.00 94.00 0:44 -- 128 R 4877.00 4972.00 95.00 0:29 -- 197 R 4972.00 5067.00 95.00 0:41 -- 139 R 5067.00 5161,00 94,00 0:37 -- 152 R 5161.00 5256.00 95.00 0:36 -- 158 30 750 1350 1500 80 30 750 1350 1500 80 30 750 1350 1500 80 30 750 1350 1500 80 30 750 1400 1600 80 5 4791,00 0.21 64.01 0,02 5 4886.00 0.22 65.24 0.01 5 4981,00 0.22 47.23 0,07 5 5075.00 0.15 41.66 0,08 5 5170,00 0.21 11.58 0.12 R 5256,00 5351,00 95,00 0:55 -- 104 R 5351.00 5395.00 44.00 0:22 -- 120 R 5395.00 5444.00 49.00 0:23 -- 128 R 5444.00 5540.00 96.00 0:58 -- 99 R 5540,00 5634.00 94,00 1:05 -- 87 30 750 1400 1600 80 30 750 1500 1600 80 30 750 1500 1600 80 30 750 1450 1550 80 30 750 1400 1550 80 5 5264.00 0.23 18.61 0.04 5 5359.00 0.23 16.84 0.01 5 6 5454.00 0.21 323.99 0,21 6 5548.00 0.30 301.12 0.14 5634.00 5729.00 95.00 1:04 -- 89 5729.00 5799.00 70.00 0:51 -- 82 5799.00 5823.00 24.00 0:10 -- 144 5823.00 5917.00 94.00 1:04 -- 88 5917.00 6012.00 95,00 1:47 -- 53 30 750 1400 1550 80 30 750 1400 1550 80 30 750 1400 1550 80 30 750 1400 1550 80 30 750 1400 1550 80 6 5643.00 0.27 299.15 0,03 6 5737.00 0.26 296.43 0.02 6 6 5832.00 0.27 291.28 0.03 6 5926.00 0.24 295.18 0.04 6012,00 6107.00 95.00 1:04 -- 89 6107.00 5202.00 95.00 1:52 -- 51 30 750 1400 1550 80 30 750 1400 1550 80 6021,00 0.25 292.61 0.02 6116.00 0.27 289.13 0,03 NS31\NS-31\NS31\ Page 2 of 4 5/23/2001-12:29 AM (PJS) (ft) (fi) {fi) (hr:min) (°) (ftJh) (1000 lb0 (galJmin) (ps) (ps) / (A) (~t) (o) ° I(°z !00 ~t) l R 6202.00 6297.00 95.00 1:02 -- 92 40 750 1350 1500 80 7 6210.00 0.28 287.17 0.01 R 6297.00 6392.00 95.00 1:00 -- 95 40 750 1400 1600 80 6 6305.00 0.29 156,09 0.55 6392.00 6487.00 95.00 1:02 -- 92 43 750 1400 1650 80 R 6487.00 6579.00 92.00 0:53 -- 104 R 6579.00 6674.00 95.00 1:48 -- 53 R 6674.00 6768.00 94.00 1:55 -- 49 R 6768.00 6861.00 93.00 1:35 -- 59 R 6861.00 6955.00 94.00 2:05 -- 45 43 750 1400 1650 80 43 750 1400 1650 80 43 750 1450 1650 80 43 750 1450 1650 80 43 750 1450 1650 90 6 6399.00 0.25 287.91 0.52 7 6494.00 0.26 286,59 0.01 7 6588.00 0.29 285.01 0.03 7 6683.00 0.38 286,36 0.10 7 6778.00 0.39 290.34 0.03 7 6872.00 0.39 293.13 0.02 R 6955.00 6979.00 24.00 0:25 -- 58 R 6979.00 7050.00 71.00 0:37 -- 115 R 7050.00 7072.00 22.00 0:30 -- 44 R 7072.00 7166.00 94.00 1:23 -- 68 R 7166.00 7263.00 97.00 1:30 -- 65 R 7263.00 7288.00 25.00 0:28 -- 54 R 7288,00 7358,00 70.00 0:57 -- 74 S 7358.00 7389.00 31.00 0:57 M60 33 R 7389,00 7453,00 64.00 1:07 -- 57 S 7453,00 7483.00 30.00 1:02 M60 29 R 7483.00 7646.00 83.00 1:01 -- 62 R 7546.00 7641.00 95.00 1:24 -- 68 S 7641,00 7671.00 30.00 0:57 G-20 32 R 7671.00 7735.00 64.00 1:04 -- 60 S 7735,00 7765.00 30,00 0:57 G 0 32 10 800 2000 2400 50 8 800 2000 2500 50 8 800 1900 2000 50 6 750 1550 1800 50 8 750 1550 2000 50 8 750 1550 2000 50 8 750 1550 2000 50 10 760 1700 1850 0 8 760 1600 1900 50 10 760 1600 1750 0 8 760 1600 1900 50 8 760 1600 1900 50 6 760 1600 1750 0 8 760 1600 1900 50 6 760 1600 1900 0 7 6967.00 0.48 299.64 0.11 6 6 7061.00 0.48 288.64 0.10 6 7156.00 0,52 301.59 0.13 7 7251.00 0.46 334.07 0.29 7 7 7345.00 0.46 347.20 0,11 0 7 7440.00 1.77 47.59 1.68 0 7 7534.00 3.49 54,50 1.86 7 7629.00 4.19 53,81 0.74 0 7 7723.00 5.44 46.25 1,49 0 R 7765.00 7830,00 65.00 1:04 -- 61 S 7830.00 7861.00 31.00 1:11 G 10 26 R 7861,00 7925,00 64.00 1:13 -- 53 S 7925.00 7965.00 40.00 1:24 G 0 29 R 7965.00 8020.00 55,00 1:10 -- 47 S 8020.00 8060.00 40.00 1:09 G-20 35 R 8060.00 8114.00 64.00 1:08 -- 48 S 8114.00 8154.00 40.00 1:07 G-20 36 R 8154.00 8210.00 56.00 1:19 -- 43 S 8210.00 8255,00 45.00 1:18 G 0 35 R 8255.00 8303.00 48.00 1:16 -- 38 S 8303.00 8348.00 45.00 1:27 , G 20 31 R 8348.00 8398.00 50.00 1:06 -- 45 S 8398,00 8443.00 45.00 1:35 G 0 28 R 8443,00 8492,00 49.00 1:07 -- 44 8 760 1600 1900 50 6 760 1650 1800 0 8 760 1650 1950 50 5 760 1700 1850 0 8 760 1750 2000 50 8 760 1750 1900 0 8 760 1800 2100 50 8 760 1800 1900 0 8 760 1800 2100 50 10 760 1900 2100 0 8 760 1700 2100 50 10 760 1700 1900 0 8 760 1700 2000 50 8 760 1850 2000 0 8 760 1850 2150 50 7 7818.00 6.61 49.37 1.28 7 6 7913.00 8.37 51.65 1.88 0 7 8007.00 10.27 51.36 2.02 0 6 8102.00 12.50 49.68 2.37 0 6 8196.00 14,67 47.25 2.39 0 6 8291.00 16.97 48,98 2.47 0 6 8385.00 19.34 50.88 2.60 0 6 8480,00 21.40 49.81 2,20 S 8492.00 8542.00 50.00 1:34 G-10 32 R 8542.00 8570.00 28.00 0:32 -- 53 R 8570.00 8587,00 17.00 0:33 -- 31 R 8587.00 8682.00 95.00 1:45 -- 54 S 8682.00 8712,00 30,00 0:47 G 0 38 5 760 1950 2150 0 8 760 1950 2250 50 8 760 1950 2250 50 8 760 2000 2300 100 8 760 2050 2250 0 0 6 6 8575.00 23.60 49.58 2.32 6 8669.00 24.81 48,28 1.41 0 8712.00 8777.00 65.00 1:29 -- 44 8777,00 8872.00 95.00 1:56 -- 49 8872,00 8968.00 96,00 1:48 -- 53 8968.00 9061.00 93.00 2:17 -- 41 9061.00 9115.00 54.00 0:44 -- 74 8 760 2050 2300 50 8 760 2000 2400 60 8 760 2000 2300 50 8 760 2050 2400 50 8 760 2000 2300 50 6 8764.00 24.21 49,25 0.76 6 8858.00 23.69 48,60 0.62 6 8953.00 23.52 49,34 0.36 6 9048.00 22.79 49.87 0.80 6 R 9115.00 9155.00 40.00 1:06 -- 36 R 9155.00 9250.00 95.00 2:44 -- 35 R 9250.00 9330.00 80.00 1:45 -- 46 R 9330.00 9343.00 13.00 0:22 -- 35 R 9343.00 9438.00 95.00 1:55 -- 50 R 9438.00 9534.00 96.00 1:53 -- 51 R 9534,00 9629.00 95.00 1:38 -- 58 R 9629.00 9725.00 96.00 1:29 -- 65 R 9725.00 9816.00 91.00 1:22 -- 67 R 9816.00 9912.00 96.00 1:28 -- 65 10 760 2000 2300 50 14 780 2050 2450 50 14 760 2050 2450 50 18 760 2050 2450 50 18 760 2050 2500 50 20 760 2500 3000 50 25 760 2600 3100 50 25 760 2650 3150 50 25 760 2600 3150 50 25 760 2600 3150 50 8 9142.00 22.58 49.89 0.22 8 9237.00 22.00 49,47 0,63 8 8 9331.00 21,01 49,39 1.05 8' 9426.00 20.36 49,79 0,70 8 9520.00 19.55 49,14 0.89 8 9615.00 19.11 49.33 0.47 9 9710.00 17.97 49.37 1.20 9 9804.00 17.46 47.11 0.91 9 9899.00 16.91 46.95 0,58 N S 31 \N S-3 I\N S31 \ Page 3 of 4 5/23/2001 -12:29 AM (R/S) (ft) (fi) (ft) (hr. min) (°) (ft/h) (1000 lb0 (gal/rain) (ps) (ps) | (A) (ft) (°) (°) I(° / 100 ft) l R 9912.00 10007.00 95.00 1:21 -- 70 22 760 2700 3200 50 R 10007.00 10101.00 94.00 1:16 -- 74 22 760 2700 3200 50 R 10101.00 10196.00 95.00 1:21 -- 70 22 760 2700 3200 50 R 10196.00 10291.00 95.00 1:10 -- 81 22 760 2800 3300 50 R 10291.00 10386.00 95.00 1:22 -- 70 25 760 2800 3200 50 R 10386.00 10406.00 20.00 0:17 -- 71 25 760 2900 3300 50 R 10406.00 10479.00 73.00 1:14 -- 59 25 760 2850 3500 50 R 10479.00 10574.00 95.00 1:53 -- 50 18 760 2850 3300 50 R 10574.00 10611.00 37.00 0:51 -- 44 22 760 2850 3500 50 R 10611.00 10669.00 58.00 3:06 -- 19 30 760 2850 3200 50 9 9993.00 16.58 46.79 0.35 9 10088.00 15.96 47.03 0.66 9 10182.00 15.38 46,72 0.62 10 10277.00 14,93 46.47 0.48 10 10372.00 13.99 46,99 1.00 10 11 10466.00 13.24 47.51 0.81 10 10561.00 12.85 47.18 0.42 11 9 10643.00 12.31 46.07 0.72 R 10669.00 10761.00 92.00 4:26 -- 21 30 760 2800 3100 50 R 10761.00 10857.00 96.00 4:25 -- 22 30 760 2800 3100 50 R 10857.00 10945.00 88.00 4:14 -- 21 14 760 2800 3100 50 R 10945.00 10965.00 20.00 1:01 -- 20 35 525 1000 1000 100 R 10965.00 11008.00 43.00 2:54 -- 15 40 460 850 850 120 9 10712.00 11.55 46.46 1.11 9 10808.00 10.81 48,09 0.84 10 10902.00 10.24 51.20 0.86 8 9 10998.00 10.12 50,03 0.25 11008.00 11015.00 7.00 11015.00 11058.00 43.00 11058.00 11086.00 28.00 11086,00 11110.00 24.00 11110.00 11206.00 96.00 0:10 -- 42 40 460 850 850 120 2:37 -- 16 40 460 850 850 100 0:23 -- 73 40 460 825 825 100 0:25 -- 58 40 460 825 825 100 1:58 -- 49 40 460 800 800 100 9 10 10 10 11093.00 9.53 49.17 0.64 14 11188.00 9.32 48,03 0.30 R 11206.00 11302.00 96.00 R 11302.00 11394.00 92.00 R 11394.00 11440.00 46.00 3:26 -- 28 40 460 800 800 100 8:21 -- 11 40 460 1150 1150 100 6:52 -- 7 43 460 1150 1150 100 12 11283.00 8.93 47,65 0.42 11 11378.00 8.36 47.39 0.60 11421.00 7.85 48.19 1.21 10 11440,00 7.62 48.55 1.24 NS31\NS-31\NS31\ Page 4 of 4 5123/2001-12:29 AM ilii Customer: BP ALASKA C'"---~sing Pr-~ogram 2~ inct~-at 199 iiii,,,, sperry-sun WelhNS31 133/8" inch at 3237 ,t ilii Area: BEAUFORT SEA,ALASKA 9 5/8" inch at 10927 ft .... !iii Lease: NORTHSTAR inch at ft iilJ DRILLING SERVICES Rig: NABORS DRLG RIG 33E inch at ft iii..=~ Mud Company: BAROID inch at ft iii' Bit Record Job No.: AK-AM 10142 !!1)(~--.~' ~. .... /~~~ ............................ ..)~tfl)tllttttttltlltlltllllfltlf~tttttlltllt~ "ii Date Bit Bit Serial Size IFA Depth Depth Feet Hours ReP BHA KREV Slide ii{ No. Type Number In Out ft/hr % GRADE ,~,104/29/01 1 MX-C1 R89DW 16 1.224 199 3249 3050 18.7 163 1 220K 13 1-2-WT-A-E.-I-PN-TD ~!i~04/29/01 1RR MX-C1 R89DW 16 1.224 199 3249 3050 18.7 163 2 220K 13 1-2-WT-A-E-I-PN-TD '~"'05/05/01 3 MX-C1DX F58DH 12.25 1.006 3249 6955 3706 37 100 3 361K 6-5-WI-A- E.. 1/16-FC-ROP iiii, 05/05/01 4 DSO7+GNV 101161 12.25 1.035 6955 10945 3990 83.1 48 4 1625K 14 4-2-Re-N-X- 1/16-BU-TD i!Ji 05/19/01 5 20MFDGPS MJ0685 8.5 1.804 10945 11440 495 28.1 18 5 169K 7- 8. BT-A-.E-I-.ID-TD .... .... i".- t i iii'.-.- iii-..' !:t~' ~.'.H '~11":. ilii; Customer: BP ALASKA Casing Program 20 inch at 159 ft1 sperry-sun Well: NORTHSTARNS31 133,8" ,nchat 3237 ft1 i};ii Area: ~~ iili! Lease: ~ ' inch at ft ' inch at ft! ,:,,...~,,'-.-~ DRILLING SERVICES Rig: NABORS DRILLING RIG 33E ,iii! Mud Company: BAROID DRILLING FLUIDS inch at !li!i Waterbase Mud Record Job No.: AK-~014-"~~~ ~iJJ~'~ I~ DaJe Deplh ~w Vis PV YP Gels Flit HTHP Cake Sol Oil Water Sd CEC pH Pm Pf / I ~ Iblgal sec cp LBll00 10S / 1O~ ~lJ~0 ml~deg F 32's % % % % mg,m~ ppm ppm ~i~ 04/1110i l l2? B.~ 18~ S0 ~ l~ I ~8 lI.l 0.0 ~l.0 1.~ 8.4 0.10 .1 /.~ ~1000 iii 0SI08/01 8~Z ~.~ 48 ll 2S l0 1 18 ~.~ l~.~ ~ 2.0 ~l.0 0.~ 8.~ 0.~0 .~ I 1.4 ~0000 il!~ ~ ~.~ 44 il ~ il 118 ~.~ ii.8 l l.o ~o.~ o.l~ 8.~ o.io .ili.~ 4~ooo ~o ;iii 05/11/01 10626 11.3 41 16 25 12 / 23 5.6 11.5 2 2.0 84.2 0.25 8.3 0.10 .1 / 1.5 52000 1160 ~ 05/12101 10945 11.3 45 17 28 14121 4.8 10.6 2 2.0 84.1 0.25 8.0 011.5 53000 1280 ~{ 05/13/01 10945 11.3 42 16 24 13120 5.1 11.0 2 2.0 84.1 0.25 8.0 011.5 52000 1100 ~ 05/14/01 10945 11.3 43 16 24 13 / 20 5.1 11.0 2 2.0 84.~ 0.25 8.0 011.5 52000 1220 ~{{ 05/16/01 10945 10.1 42 13 26 8 / 11 3.4 1 0.0 95.8 0 9.0 0 / .3 21000 ~ os, 7/o~ ~o~s ..3 ~2 ~3 2s s/~ 3.~ ~:~ ~ ~.0 .~.0 0 ,.0 .~/.3 2~000 ~0 ~ 05/18/01 10945 9,3 39 11 20 8 / 10 5.1 9.9 1 1.0 94.0 0 8.8 0/.3 19000 600 ~il~ 05/19/01 10945 9.3 40 11 20 8/11 4.9 9.8 1 1.0 94.0 0 8.7 0/.3 19000 ~0 . ... ..o =oooo NS31 Final Survey - Gyro Schlumberger Client: BPXA Field: Northstar Structure: Nocthstar PF Well: NS-31 Borehole: NS31 UWlIAPI#: 50-029-23009-00 Date: May 17, 2001 Grid Convergence: 1.23167528° Scale Factor:. 0,99992902 Location: N 70 29 29,647, W 148 41 36.010 : N 6031121.200 ftUS, E 659822.100 flUS Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Survey Computation Method: Minimum Curvature DLSComputation Method: Lubinski Vertical Section Azimuth: 52,230° Vertical Section Odgin: N 0.000 ff, E 0,000 ff TVD Reference: Borehole: KB 56.0 ft above MSL Magnetic Declination: 26.817° Total Field Strength: 57502.155 nT Dip: 80.916° Declination Date: April 24, 2001 Magnetic Declination Model: BGGM 2001 North Reference: True North Coordinate Reference To: Wellhead (True) I'l (~) (°) (°) ¢) ¢) 0.00 0.00 0.00 0.00 0.00 91.00 0.18 52.92 91.00 0.14 182.00 0.25 49.14 182.00 0.48 273.00 0.25 41.21 273.00 0.88 364.00 0.32 54.88 364.00 1.33 455.00 0.50 80.25 454.99 1.93 547.00 0.91 97.94 546.99 2.79 638.00 1.42 102.98 637.97 4.01 728.00 2,39 94.90 727.92 6.10 819.00 2.92 91.77 818.82 9.28 914.00 3.83 93.09 913.65 13.55 1008.00 4.54 91.48 1007.40 18.80 1103.00 4.97 90.97 1102.08 24.92 1198.00 4.66 91.84 1196.74 31.11 1292.00 4.72 92.34 1290.43 37.01 1387.00 4.99 93.88 1385.09 43.08 1481.00 4.82 95.98 1478.74 48.99 1576.00 4.36 94.12 1573.44 54.56 1670.00 3.69 95.04 1667.20 59.44 1765.00 3.77 95.49 1762.00 63.96 1860.00 3.35 92.86 1856.82 68.34 1954.00 1.69 72.62 1950.73 71.72 2049.00 0.97 56.98 2045.70 73.84 2143.00 1.01 56.25 2139,69 75.46 2238,00 1.07 57.65 2234.67 77.17 2332.00 0.92 61.87 2328.66 78.79 2427.00 0.47 83.65 2423.65 79.88 2522.00 0.42 85.64 2518,65 80.50 2616.00 0.44 86.10 2612.64 81.09 2711.00 0.41 87.92 2707.64 81.67 I 2805.00 0.37 89.54 2801.64 82.18 2900.00 0.35 91.29 2896.64 82:65 2995.00 0.37 90.10 2991.64 83.12 3089.00 0.29 97.76 3085.63 83.52 3184.00 0.13 102.38 3180.63 83.76 3278.00 0.15 91.39 3274.63 83.92 3373.00 0.20 63.28 3369.63 84.18 3467.00 0.19 51.84 3463.63 84.50 3562.00 0.30 52.71 3558.63 84.91 3657.00 0.37 51.17 3653.63 85.46 3751.00 0.45 50.48 3747.63 86.13 3846.00 0.47 54.47 3842.62 86.90 3940.00 0.46 57.38 3936.62 87.66 I 31\NS-31\NS31\NS31 Gyro NS 0.00 0.09 0.30 0.58 0.88 1.09 1.06 0.70 0.29 0.06 -0.19 -0.45 -0.62 -0.81 -1.09 -1.53 -2.22 -2.89 -3.42 -3.98 -4.42 -4.14 -3.29 -2.39 -1.45 -0.63 -0.23 -0.16 -0.11 -0.07 -0.05 -0.06 -0.07 -0.10 -0.15 -0.18 -0.11 0.06 0.31 0.65 1.08 1.54 1.97 EW I TF (fi) t Closure (~A~im 0.00 0.00 0.00 52.9 0.11 0.14 285.80 49.1 0.38 0.48 336.55 41.2 0.66 0.88 11.51 54.9 1.00 1.33 15.45 80.3 1.60 1.93 21.73 97.9 2.72 2.91 26.96 103.0 4.53 4.59 40.03 94.9 7.49 7.49 61.46 91.8 11.69 11.69 76.82 93.1 17.28 17.28 82.91 91.5 24.14 24.14 83.61 91.0 32.01 32.01 85.20 91.8 39.98 39.99 86.54 92.3 47.66 47.67 87.49 93.9 55.69 55.71 87.81 96.0 63.69 63.73 87.98 94.1 71.27 71.32 88.62 95.0 77.84 77.92 89.14 95.5 84.00 84.09 89.72 92.9 89.88 89.99 90.04 72,6 93.94 94.04 90.18 57.0 95.96 96.01 90.53 56.2 97.31 97.34 90.62 57.6 98.76 98.77 90,22 61,9 100.16 100.17 89.62 83.7 101.22 101.22 89.03 85.6 101.96 101.96 88.46 86.1 102.66 102.66 88.12 87.9 103.37 103.37 88.02 89.5 104.01 104.01 87.95 91.3 104.60 104.60 87.85 90.1 105.20 105.20 87.77 97.8 105.74 105.74 87.68 102.4 106.08 106.08 87.60 91.4 106.31 106.31 87.55 63.3 106.58 106.58 87.53 51.8 106.85 106.85 87.53 52.7 107.17 107.17 87.50 51,2 107.61 107,61 87.35 50.5 108.13 108.14 86.85 54.5 108,73 108.75 86.64 57.4 109.37 109.38 86.41 58.0 J DLS ¢/lOO,) I Comment M --- Tie-In M 0.20 Gyro Survey M 0.08 Gyro Survey M 0.04 Gyro Survey M 0.11 Gyro Survey M 0.28 Gyro Survey M 0.50 Gyro Survey M 0.57 Gyro Survey M 1.12 Gyro Survey M 0.60 Gyro Survey M 0.96 Gyro Survey M 0.77 Gyro Survey M 0.45 Gyro Survey M 0.34 Gyro Survey M 0.08 Gyro Survey M 0.32 Gyro Survey M 0.26 Gyro Survey M 0.51 Gyro Survey M 0.72 Gyro Survey M 0.09 Gyro Survey M 0.47 Gyro Survey M 1.98 Gyro Survey M 0.84 Gyro Survey M . 0.04 Gyro Survey M 0.07 Gyro Survey M 0.18 Gyro Survey M 0.54 Gyro Survey M 0.06 Gyro Survey M 0.02 Gyro Survey M 0.03 Gyro Survey M 0.04 Gyro Survey M 0.02 Gyro Survey M 0.02 Gyro Survey M 0.10 Gyro Survey M 0.17 Gyro Survey M 0.04 Gyro Survey M 0.10 Gyro Survey M 0.04 Gyro Survey M 0.12 Gyro Survey M 0.07 Gyro Survey M 0.09 Gyro Survey M 0.04 Gyro Survey M 0.03 Gyro Survey Page 1 of 3 '**Projections and Interpolations in Italics** 5/23/2001-12:23 AM 4035.00 0.47 57.97 4129.00 0.37 58.25 4224.00 0.38 62.98 4319.00 0.37 62.05 4413.00 0.27 85.30 4508.00 0.27 71.54 4602.00 0.19 61.26 4697.00 0.19 62.13 4791.00 0.21 64.01 4886.00 0.22 65.24 4981.00 0.22 47.23 5075.00 0.15 41.66 5170.00 0.21 11.58 5264.00 0.23 18.61 5359.00 0.23 16.84 5454.00 0.21 323.99 5548.00 0.30 301.12 5643.00 0.27 299.15 5737.00 0.26 296.43 5832.00 0.27 291.28 5926.00 0.24 295.18 6021.00 0.25 292.61 6116.00 0.27 289.13 6210.00 0.28 287.17 6305.00 0.29 156,09 6399.00 0.25 287.91 6494.00 0.26 286.59 6588,00 0.29 285.01 6683.00 0.38 286.36 6778.00 0.39 290.34 6872.00 0.39 293.13 6967.00 0.48 299.64 7061.00 0.48 288,64 7156.00 0,52 301.59 7251.00 0.46 334.07 7345.00 0.46 347.20 7440.00 1.77 47.59 7534.00 3.49 54.50 7629.00 4.19 53.81 7723.00 5.44 46.25 7818.00 6.61 49.37 7913,00 8.37 51.65 8007.00 10.27 51.36 8102.00 12.50 49.68 8196.00 14,67 47.25 8291.00 16.97 48.98 8385.00 19.34 50.88 8480.00 21.40 49.81 8575.00 23.60 49.58 8669.00 24.81 48.28 8764.00 24.21 49.25 8858.00 23.69 48.60 8953.00 23.52 49.34 9048.00 22.79 49.87 9142.00 22.58 49.89 9237.00 22.00 49.47 9331.00 21.01 49.39 I 31 ',NS-31\NS31\NS31 Gyro TVD 4031.62 4125.62 4220.61 4315.61 4409.61 4504.61 4598.61 4693.61 4787.61 4882.61 4977.61 5071.60 5166.60 5260.60 5355.60 5450.60 5544.60 5639.60 5733.60 5828.60 5922.60 6017.60 6112.60 6206.59 6301.59 6395.59 6490.59 6584.59 6679.59 6774.59 6868,59 6963.58 7057.58 7152.58 7247.57 7341.57 7436.55 7530.45 7625.23 7718.90 7813.38 7907.56 VSec 88.43 89.11 89.73 90.34 90.82 91.22 91.58 91.89 92.22 92.56 92,92 93.22 93.48 93.77 94.08 94.24 94.16 93.98 93.80 93.59 93.39 93.20 92,97 92.72 92.53 92.36 92.11 91.84 91.51 91.16 90.83 90.52 90.16 89.78 89.71 89.95 91,57 95.88 102.23 110.10 120.04 132.41 NS 2.38 2.75 (ft) Icl°sure (,) Ic~ 110.02 110.04 86.18 110.60 110.64 85.95 3.05 111.14 111.19 85.77 3.34 111.70 111.75 85.65 3.50 112.18 112.24 85.54 3.59 112.62 112.68 85.43 3.73 112.97 113.03 85.41 3.88 113.24 113.31 85.46 4.03 113,54 113.61 85.52 4.18 113.86 113.94 85.56 4.38 114.16 114.24 85.57 4.60 114.37 114.47 85.60 4.86 114.49 114.59 85.64 5.21 114.59 114.70 85.64 5.57 114.70 114.84 85.63 5.90 114.65 114.81 85.51 6.16 114.34 114.51 85.33 6.40 113.93 114.11 85.22 6.60 113.55 113.74 85.22 6.78 113.15 113.35 85.15 6.94 112.76 112.98 85.01 7.11 112.39 112.62 85.00 7.26 111.99 112.22 85.04 7.40 111.56 111.81 85.07 7.25 111.44 111,67 85.07 7.10 111.34 111.56 85.08 7.22 110.93 111.17 85.08 7.34 110.50 110.74 85.09 7.49 109.96 110.22 85.09 7,70 109.36 109,63 85.02 7.93 108.77 109,05 84,94 8.26 108,12 108.44 84.82 8.58 107.41 107.75 84.71 8.93 106.66 107,04 84.49 9.50 106,13 106.55 84.23 10.21 105.88 106.37 83.90 11.57 106.88 107.50 83.04 14.21 110.28 111.19 81.78 17.94 115.44 116.82 80,21 23.05 121.43 123.59 78.14 29.72 128.83 132.21 75.92 37.57 138.40 143.41 73.79 8000.32 147.64 47.05 150.31 157.50 71.62 8093.44 166.38' 58.99 164.77 175.01 69.21 8164.81 188.40 73.66 181.27 195.66 66.79 8276.20 214.23 90.92 200.56 220,21 64.68 8365.52 243.49 109.75 222.99 248.54 63,08 8454.57 276.54 130.86 248.44 280.80 61.77 8542.34 312.85 154.38 276.16 316.38 60.52 8628.07 351.33 179.70 305.21 354.18 59.40 8714.51 390.66 205.68 334.84 392.97 58.47 8800.42 428.76 230.75 363.61 430.65 57.68 8887.47 8974.82 9061.54 9149,44 9236.90 255.73 392.30 468.29 57.03 279.94 420.75 505.37 56.48 303.30 448.47 541.40 56.05 326.61 475.95 577.23 55.69 349.02 502.12 611.51 55.37 466.74 504.05 540.27 576.27 610.69 TF t OLSI Comment (°) (°/lOOft) 58.2 M 0.01 Gyro Survey 63.0 M 0.11 Gyro Survey 62.1 M 0.03 Gyro Survey 85.3 M 0.01 Gyro Survey 71.5 M 0.17 Gyro Survey 61.3 M 0.07 Gyro Survey 62.1 M 0.10 Gyro Survey 64.0 M 0.00 Gyro Survey 65.2 M 0,02 Gyro Survey 47.2 M 0.01 Gyro Survey 41.7 M 0,07 Gyro Survey 11.6 M 0,08 Gyro Survey 18.6 M 0.12 Gyro Survey 16.8 M 0.04 Gyro Survey -36.0 M 0.01 Gyro Survey -58.9 M 0.21 Gyro Survey -60.9 M 0.14 Gyro Survey -63.6 M 0.03 Gyro Survey -68.7 M 0,02 Gym Survey -64.8 M 0,03 Gyro Survey -67.4 M 0.04 Gyro Survey -70.9 M 0.02 Gyro Survey -72.8 M 0.03 Gyro Survey 156.1 M 0.01 Gyro Survey -72.1 M 0.55 Gyro Survey -73.4 M 0.52 Gyro Survey -75.0 M 0.01 Gyro Survey -73.6 M 0.03 Gyro Survey -69.7 M 0.10 Gyro Survey -66.9 M 0.03 Gyro Survey -60,4 M 0.02 Gyro Survey -71,4 M 0.11 Gyro Survey -58.4 M 0.10 Gyro Survey -25.9 M 0.13 Gyro Survey -12.8 M 0.29 Gyro Survey 47.6 M 0.11 Gyro Survey 54.5 M 1.68 Gym Survey 53,8 M 1.86 Gyro Survey 46.3 M 0.74 Gyro Survey 17.2 G 1.49 Gyro Survey 10.7 G 1.28 Gyro Survey -1.6 G 1.88 Gyro Survey -9.3 G 2.02 Gyro Survey -15.9 G 2.37 Gyro Survey 12.4 G 2.39 Gyro Survey 14.9 G 2.47 Gyro Survey -10.8 G 2.60 Gyro Survey -2.4 G 2.20 Gyro Survey -24.4 G 2.32 Gyro Survey 146.6 G 1.41 Gyro Survey -153.4 G 0.76 Gyro Survey 120.2 G 0.62 Gyro Survey 164.3 G 0.36 Gyro Survey 177.9 G 0.80 Gyro Survey -164.8 G 0.22 Gyro Survey -178.3 G 0.63 Gyro Survey 167.9 G 1.05 Gyro Survey Page 2 of 3 '*Projections and Interpolations in Italics'* 5t23/2001-12:23 AM MD ' Incl ° I TF ¢) (") 1 ~m (ft>Ic~-ur° 'm <°> 1 9426.00 20.36 49.79 9325.78 644.21 370.78 527.67 644.91 55.07 -165.0 G 9520.00 19.55 49.14 9414.13 676.25 391.62 552.05 676.85 54.80 172.0 G 9615.00 19.11 49.33 9503.78 707.65 412.16 575.87 708.17 54.56 179.4 G 9710.00 17.97 49.37 9593.84 737.82 431.83 598.79 738.26 54.35 -127.6 G 9804.00 17.46 47.11 9683.39 766.35 450.87 620.13 766.71 54.14 -175.2 G 9899.00 16.91 46.95 9774.14 794.30 470.00 '640.66 794.58 53.92 -172.1 G 9993.00 16.58 46.79 9864.16 821.27 488.52 660.43 821.47 53.71 173.9 G 10088.00 15.96 47.03 9955.35 647.77 506.70 679.87 847.92 53.51 -171.9 G 10182.00 15.38 46.72 10045.86 873.05 524.06 698.40 873.15 53.32 -171.9 G 10277.00 14.93 46.47 10137.56 897.76 541.12 716.44 897.83 53.12 172.4 G 10372.00 13.99 46.99 10229.55 921.37 557.38 733.71 921.42 52.94 171.0 G 10466.00 13.24 47.51 10320.90 943.42 572.41 749.96 943.44 52.79 -169.3 G 10561.00 12.85 47.18 10413.45 964.78 586.94 765.73 964.80 52.67 -156.4 G 10643.00 12.31 46.07 10493.48 982.56 599.20 778.71 982.56 52.55 174.1 G 10712.00 11.55 46.46 10560.99 996.74 609.06 789.02 996.74 52.45 157.7 G 10808.00 10.81 48.09 10655.17 1015.28 621.69 802.68 1015.28 52.40 136.6 G 10902.00 10.24 51.20 10747.59 1032.43 632.82 815.75 1032.43 52.38 -120.7 G 10998.00 10.12 50.03 10842.08 1049.39 643.58 828.87 1049.39 52.35 -166.5 G 11093.00 9.53 49.17 10935.68 1065.58 654.09 841.22 1065.58 52.31 -138.9 G 11188.00 9.32 48.03 11029.40 1081.11 664.37 852.89 1081.11 52.25 -171.4 G 11283.00 8.93 47.65 11123.20 1096.13 674.48 864.05 1096.14 52.19 -176.2G 11378.00 8.36 47.39 11217.12 1110.36 684.13 874,59 1110,37 52,13 167.9 G 11421.00 7.85 48.19 11259.69 1116.41 688.20 879.08 1116.42 52.11 168.3 G 11440.00 7.62 48.55 11278,52 1118.96 689.90 880.99 1118.97 52.10 --- BLS I Comment (°/100ft) 0.70 Gyro Survey 0.89 Gyro Survey 0.47 Gyro Survey 1.20 Gyro Survey 0.91 Gyro Survey 0.58 Gyro Survey 0.35 Gyro Survey 0.66 Gyro Survey 0.62 Gyro Survey 0.48 Gyro Survey 1.00 Gyro Survey 0.81 Gyro Survey 0.42 Gyro Survey 0.72 Gyro Survey 1.11 Gyro Survey 0.84 Gyro Survey 0.86 Gyro Survey 0.25 Gym Survey 0.64 Gyro Survey 0.30 Gyro Survey 0.42 Gyro Survey 0.60 Gyro Survey 1.21 Gyro Survey 1.24 Projection to TD 31\NS-31\NS31\NS31 Gyro Page 3 of 3 '*Projections and Interpolations in Italics" 5/23/2001-12:23 AM NS-31 Formation Tops Formation Prognosed Tops Actual Depths TVDss I TVDrkb MDrkb TVDss TVDrkb MDrkb Top Permafrost 1.150 1,205 1,207 1,150 1,205 1,207 Base Permafrost 1,500 1,555 1,558 1,500 1,555 1,558 SV6 -Top Confining Zone 3.009 3,065 3,069 3,010 3,066 3,070 Surface Casing Point 3,159 3,215 3,219 3,190 3,246 3,249 SV5 - Base Confining Zone 3.289 3,345 3,349 3,279 3,335 3,337 SV4 3,589 3,645 3,649 3,591 3,647 3,650 SV2 -Top Upper Injection Zone 3,989 4,045 4,049 3,997 4,053 4,056 SV1 - Top Major Shale Barrier 4,369 4,425 4,429 4,389 4,445 4,448 TMBK - Top Lower Injection Zone - Top Ugnu 4.719 4,775 4,779 4,741 4,797 4,800 M87F - Top Schrader Bluff - Base Ugnu 6,314 6,370 6,374 6,339 6,395 6,398 M60T- Base Lower Injection Zone (top Colville) 6,884 6,940 6,939 6,939 6,959 6,995 THRZ _ Top HRZ 8,514 8,570 8,607 8,664 8,720 8,781 BHRZ- Base HRZ 8,594 8,650 8,694 8,744 8,800 8,861 Top Kuparuk 8,664 8,720 8,771 8,819 8,875 8,945 Kuparuk C 8,864 8,920 8,989 8,929 8,985 9,055 Top Miluveach 8,994 9,050 9,131 9,184 9,240 9,310 Top Kingak 9,494 9,550 9,679 9,600 9,656 9,780 Fault 50 (estimated 100' throw) 9,670 9,726 9,855 9,700 9,756 9,880 Top Sag River 10,644 10,700 10,930 10,658 10,714 10,865 Intermediate Casing Point 10,664 10,700 10,930 10,718 10,772 10927 Top Shublik 10,744 10,800 11,039 10,941 10,797 10,957 Top Ivishak 10,844 10,900 11,148 10,849 10,905 11,065 Top Kavik 11,164 11,220 11,497 11,170 11,226 11,383 Total Depth 11,224 11,280 11,562 11,224 11,280 11,440 Top Lisburne 11,289 1 !,345 11,627 11,303 11,359 11,519 ALASKA OIL AND GAS CONSERVATION COM~HSSION Floyd Hemandez Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Northstar Unit NS31 BP Exploration (Alaska) Inc. Permit No: 201-060 Sur Loc: 1348' NSL, 649' WEL, SEC. 11, T13N, R13E, UM Btmhole Loc. 2254' NSL, 4759', WEL, SEC. 12, T13N, R13E, UM Dear Mr. Hernandez: Enclosed is the approved applicatiOn for permit to drill 'the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. , BloWout prevention equipment (BOPE) mUst be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. .,~.incerely,_. ,,~ ~ Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~- ~ day of~2001 jjcfEnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA__~, .,:.. ALA~ . OIL AND GAS CONSERVATION L;O~-. ,IISSION PERMIT TO DRILL 20 AAC 25.005 I a. Type of work ~ Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 55.77' Northstar Unit 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 312799 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1348' NSL, 649' WEL, SEC. 11, T13N, R13E, UM Northstar Unit At top of productive interval 8. Well Number 2091' NSL, 4952' WEL, SEC. 12, T13N, R13E, UM NS31 Number 2S100302630-277 At total depth 9. Approximate spud date 2254' NSL, 4759' WEL, SEC. 12, T13N, R13E, UM 03/30/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL Y0181 / 312808I NS29 is 15' away at 600' 4472 11563' MD / 11281' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 7500' MD Maximum Hole Angle 23.49 o Maximum surface 4266 psig, At total depth (TVD) 11224' / 5388 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin,q Wei.qht Grade Couplin.q Lenqth MD TVD MD TVD (include sta,qe data) 20" 20" 169# X-56 Weld 159' Surface Surface 199' 199' Driven 16" 13-3/8" 68# L-80 BTC 3179' Surface Surface 3219' 3216' 255 sx PFE, 470 sx'G', 1708 sx PFE 12-1/4" 9-5/8" 53.5# L-80 BTC-Mod 10912' Surface Surface 10952' 10721' 531 sx Econolite, 977 sxClass'G' 8-1/2" 7" 29# 13Cr NSCC 761' 10802' 10584' 11563' 11281' 182 sxClass'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner RECEIVED MAR 1 6 ZOO1 / Perforation depth: measured tI ~///i ti, Alaska Oil & Gas Cons. Commission :." Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Andy Krieger, 564-5390 Prepared By Name/Number: Terrie Hubble, 564-4628 "~)1. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Floyd Hernand ' ' .~_..~ (/'% .. ~.__ ~ Title Senior Drilling Engineer Date .: ;':: ..:. '.. :.' ...:...::.'.'.! ..:...:':...:i..;'.: :::..:' :::...,.'..~' .:'.: '...:.".': !;.... i".': .".:' '..: . .. :'.:.:: '.':'.!';:';,~ ':.: '.:.:.i':!::.:'.'.:'...'?~ :. ": '~i: ;':.'.: ..~m'!. ,s"S!~.r!..::.iu"~e:. 0~i!¥ i.:.:i:..::'.::, i..i i.':".: i::.:.?".:?.!i! i"." ::";;':' :!';'.':i.'i .'/'.::i !i.:.:.!~::.:::.'. ...'. ::~:" ?::! !:";..;.:.."....~;: Permit Number ] APl Number ] . A, pp.royal Date I See cover letter _ 150- o 2'I /~,' ~, (/~/ ] for other requirements Conditions of Approval: 'Sam~31es Required ' [] Yes ~ No 'Mud [.og Required ~;~['Yes [] No" Hydrogen Sulfide Measures [] Yes ,~l~No Directional Survey Required ,~Yes [] No Required Working Pressure for ROPE [] 2K [] 3K [] 4K ~]~5K [] 10K [] 15K [] 3.5K psi for CTU Other: ORIGINAL SI(~NED ~':.. by order of ApprovedBy .. '~' D TayiorSeamour.tj: ~ : _ : __.. . , ,Commissioner_ the commission Date ~. ~'/'~/ Form 10-401 Rev. 12-01-85 { INAL Submit In Triplicate NS31 Permit to Drill I Well Name: INS31 Well Plan Summary I Type of Well (producer or injector): I Pre-Produced Injector Northstar Slot: NS31 Surface Location: 1348' FSL, 649' FEL, Sec. 11, T13N, R13E, UM X=659822 Y=6031121 Target: 2091' FSL, 4952' FEL, Sec. 12, T13N, R13E, UM 400' Radius X = 660782 Y = 6031885 10701' TVDrkb Bottom Hole Location: 2254' FSL, 4759' FEL, Sec. 12, T13N, R13E, UM X = 660971 Y = 6032052 11281' TVDrkb I AFE Number: 1831305 I I Rig: I Nabors 33E I Estimated Start Date: I Mar 30, 2001 I I Operating days to complete: I 34 (a.m.s.I.) I55.77'/ 15.67' I I Well Design (conventional, slimhole, etc.): I Big Bore I Objective: I lvishak pre-produced injector Mud Program: Surface Hole Mud Properties: Seawater Spud Mud 16" Hole Section From Surface to -3219' MD / 3216' TVD (~15b' TVD below top SV6). Interval Density Viscosity YP Tau0 Gel APl FL pH (ppg) (seconds) 10 sec Initial 8,8 - 9,0 200 - 300 45 - 70 > 9 25 - 40 15 - 20 8,5 - 9,5 from -1555' *9.0 - 9.5 100 - 200 30 - 45 > 7 15 - 25 4 - 10 8.5 - 9.5 SV6 @ Interval TD *9.5 75 - 100 20 - 35 > 7 10 - 25 4 - 10 8.5 - 9.5 * Should gas hydrates be encountered, mud densities up to 10.2 ppg may prove necessary. Intermediate Hole Mud Properties: Inhibited KCI 12-1/4" Hole SectiOn From Surface Casing Shoe to 10952' MD / 10721' TVD (-top Sag River+20'). Interval Density (ppg) PV YP Tau0 APl/ pH HTTP FL Initial 9.0 - 9.5 10 - 25 20 - 28 4 - 7 6 - 10 8.5 - 9.5 Top HRZto 9.6-11.0 10-25 20-25 4-7 4-6/<10 8.5-9.5 top Miluveach Miluveach to 11.0 - 11.5 10 - 25 20 - 25 4 - 7 4-6 / <10 8.5 - 9.5 interval TD 0 R 1G i it A L RECEIVED ~/~R ;[ 6 ZOO/ Alaska Oil & Gas Cons. Commission Anchorage ., NS31 Permit to Drill Production Hole Mud Properties: Seawater/Barite/CaCO3 Drill-In Fluid 8-1/2" Hole Section From Intermediate Casing Shoe to 11563' MD / 11281' TVD Interval Density (PPg) I PV I YP Initial/Final 9.7 10 - 25 20 - 25 Tau0 I APl FL 4-7 4-6 pH 8.5 - 9.5 Directional:(wP4) KOP: Maximum Hole Angle: Close Approach Well: Survey Program: ±7500' MD Cantenary curve 2.5°/100' build _+_23.49° - Slant Well Surface- 20' well spacing with NS29 - 14.9' displacement at 599' MD. Gyro will be used for initial surveys and kickoff Gyros as required from surface to +/- 1000'. Standard MWD surveys from +/- 1000' to TD. Logging Program: 16" Section: Drilling: GPJDirectional Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals), CFM (connection flow monitoring) Open Hole: None Cased Hole: None 12-1/4" Section: Drilling: GR/Directional, Res, Den, Neu, PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals down to 8620' TVDrkb; thereafter, 40' intervals - 20' intervals at shows), Geochem samples from 8620' TVDrkb (40' intervals - 20' intervals at shows), CFM (connection flow monitoring) Open Hole: None Cased Hole: USlT bond Io9 - 9 5/8" casing shoe to TOC 8-1/2" Section: Drilling: GR/Directional, Res, PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (40' intervals - 20' intervals at shows), Geochem samples (40' intervals - 20' intervals at shows), CFM (connection flow monitoring) Open Hole: Quad Combo (GRIReslDenlNeulSonic), RFT pressures only Cased Hole: None RECEIVED MAR 1 6 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage NS31 Permit to Drill Formation Markers: Formation Tops MD TVDss Pore EMW (ppg) Comments Pressure (psi) Top Permafrost 1207 1150 517 8.65 Base Permafrost 1558 1500 675 8.65 SV6 3069 3009 1354 8.65 Set surface casing 150' tvd below top of SV6 SV5 3349 3289 1480 8.65 SV4 3649 3589 1615 8.65 $V2 4049 3989 1795 8.65 SV1 4429 4369 1966 8.65 Top Ugnu (UG4A) TMBK 4779 4719 2124 8.65 Top Schrader 6374 6314 2841 8.65 Top Seabee (CM3) Colville Shales 6944 6884 3098 8.65 Top HRZ 8608 8514 3831 8.65 Base HRZ 8695 8594 3867 8.65 Top Kuparuk 8771 8664 4235 9.4 Top Kuparuk C 8989 8864 4333 9.4 ToD Miluveach 9131 8994 4395 9.4 Top Kingak 9676 9494 4690 9.5 Top Sag River 10930 10644 5109 9.23 Set intermediate casing into the top of the Sag River to cover ur) the Kingak Top Shublik 11039 10744 5157 9.23 Top Ivishak 11148 10844 5205 9.23 Top Kavik 11497 11164 5359 9.23 Proposed TD 11563 11224 5388 9.23 Top Lisburne 11627 11289 5419 9.23 Casinc /Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Casing Casing Top Hole Btm Tb~l O.D. Length MD/TVDrkb MD/TVDrkb 20" 20" 169# X-56 WELD 159' Surface 199'/199' 16" 13 3/8" 68# L-80 BTC 3179' Surface 3219'/3216' 12 1/4" 9 5/8" 53.5# L-80 BTC-Mod 10912' Surface 10952'/10721' 8 1/2" 7" 29# 13Cr NSCC 761' 10802/10584' 11563'/11281' Tubing 7" 29# 13Cr NSCC 10762' Surface 10802'/10584' RECEIVED 1 G 2001 Alaska Oil & Gas Cons. Commissi0r~ Anchorage NS31 Permit to Drill Cement Calculations: The following cement calculations are based upon a two stage job using a stage tool. Casin~l I 13-3/8" Surface I Basis: Stage 1: Lead: Based on 869' of 16" open hole x 13 3/8" csg. with 50% excess. Lead TOC: -1600' Tail: Based on 750' of 16" open hole × 13 3/8" csg. with 50% excess + 80' shoe joint. Tail TOC: At -2469' MD (2465' TVD) Stage 2: Lead: Based on 1600' of 16" open hole x 13-3/8" csg. with 250% excess + csg capacity. I Sta~le I Lead TOC: Surface Total Cement / Spacer I Sta~le 2: Total Cement ! Spacer Preflush 10 bbl sea water Spacer Lead Tail Preflush Spacer Lead 75 bbl Alpha Spacer weighted to 1.0 ppg over mud weight 98 bbl/255 sx of 12.1 ppg Type 'E' Permafrost Cement. 2.17 cf/sk, BHST 60° / BHCT 55°, TT = 6.0 hrs 96 bbl / 470 sk of 15.9 ppg Premium 'G'. 1.15 cf/sk, BHST 60° / BHCT 55°, TT = 3.0 hrs None 75 bbl Alpha Spacer weighted to 1.0 ppg over mud weight 660 bbl* / 1708 sk of 12.1 ppg Type 'E' Permafrost Cement 2.17 cf/sk, BHST 60° / BHCT 55% TT = 6.0 hrs * 2 gal Cement dye in 1st 5 bbls The following cement calculations are based upon a single stage cement job. Casing 19-5/8" Intermediate I Basis: Stage 1: ILead: Based on 4222' of 12 1/4" open hole x 9 5/8" csg with 30% excess ILead TOC: At -4049' MD (4046' TVD) ~ail: Based on 2681' of 12 ¼" open hole × 9 5/8" csg with 30% excess + 80' shoe joint. rTail TOC: At -8271' MD (8257' TVD) ISta~le 1: Total Cement ! Spacer Preflush I10 bbls sea water Spacer J50 bbl Alpha Spacer weighted to 1.0 ppg over mud MW Lead 1306 bbl / 531 sk of 11.2 ppg Econolite. [3.24 cf/sk, BHST 225° / BHCT 135% TT = 4.0 hrs Tail 1200 bbl/977 sk of 15.9 ppg Premium 'G'. 11.15 cf/sk, BHST 225° / BHCT 135% TT = 4.0 hrs The following cement calculations are based upon a single stage cement job. Casing 17" Liner I Basis: Stage 1: Lead: Based on 611' of 8 1/2" open hole x 7" csg with 50% excess + 150' 9 5/8" csg x 7" csg liner lap + 200' 9 5/8" csg x 5" drillpipe above TOL + 80' shoe joint. Lead TOC: At -10602' MD (10400' TVD) Stage 1' Total Cement / Spacer I Preflush I10 bbls sea water Spacer 50 bbl Alpha Spacer weighted to 1.0 ppg over mud MW Lead 37 bbl/182 sk of 15.9 ppg Premium 'G'. 1.15 cf/sk, BHST 235° / BHCT 145°, TT = 4.0 hrs RECEIVED MAR 1 B ZOO1 Alaska 0il & Gas Cons. Commission Anchorage ., NS31 Permit to Drill Well Control: 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. Based upon calculations below BOP equipment will be tested to 5000 psi. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Intermediate Section: · Maximum anticipated BHP: 5109 psi @ 10644' TVDss - Sag River · Maximum surface pressure: 4045 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) Production Section: · Maximum anticipated BHP: 5388 psi @ 11224' TVDss - Total Depth · Maximum surface pressure: 4266 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 5000 psi (annular to 3500 psi) 8.5 ppg Seawater / 6.8 ppg Diesel Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S · Northstar is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should be followed at all times. No H2S was detected at Northstar while drilling or testing the Seal Island A-01, A-02, or A-03 exploration/appraisal wells. No H2S was detected while drilling the NS10 waste disposal well or the NS27 well. Reference: 1) Northstar/Nabors 33E H2S contingency plan - on file with AOGCC. 2) Well test hydrocarbon analyses for Seal Island A-01, A-02, and A-03 - on file with AOGCC. DRILLING CLOSE APPROACH: · No close approach issues exist while drilling NS31 except for surface proximity to NS29. NS29 has 14.9' of separation at 599' MD. NS31 passes anticollision criteria with all wells identified as a "major risk." Gyros will be run from surface to -1000' MD or until reliable MWD surveys can be taken. SURFACE HOLE SECTION: · Mudloggers will be rigged up throughout the entire section. · No significant drilling problems have been identified in the surface hole interval (0-3216' TVD) based on offset data. Good hole cleaning and management of required mud properties are key to a successful interval. · Minor tight hole conditions have been noted in the shale intervals immediately below the permafrost during short trips. · Differential sticking could be problematic in this hole section adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, .tighten fluid loss properties of mud, and string in Barofibre as required prior to penetrating sand intervals. · Lost circulation has only been noted while drilling during hole opening runs and was most likely induced by poor hole cleaning. Losses have occurred while running and cementing surface casing. The NS27 experienced losses on the surface cement job at a rate of 12 BPM. The displacement rate was lowered to 10 BPM and full returns were re-establishe4~,~u~.e~to~,--~r.~ 1 G 2001 Alaska Oil & Gas Cons. Commission Anchorage NS31 Permit to Drill i" condition and thin mud appropriately prior to pulling out of the hole to run casing, and once on bottom with casing, bring circulation up slowly and reduce mud viscosities before pumping cement. Minor losses were seen on NS29 while running the 13 3/8" surface casing. Reduced running speed eliminated losses and the casing was cemented at 10 BPM displacement rate. Hole stabilization in the shallow unconsolidated intervals can be problematic if mud properties are relaxed. Hi viscosities as used elsewhere on the North Slope should be sufficient to control any potential running gravels. Gas hydrates may be present near the base of the permafrost. NS10, NS26, NS27 and NS29 have not experienced hydrates. Mudloggers will be used continuously on NS31 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. INTERMEDIATE SECTION: · Mudloggers will be rigged up throughout the entire section. · Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indications of shallow gas were seen while drilling NS10 or NS27. Mudloggers will be used continuously on NS31 to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. A minimum of 9.0 ppg is recommended. · The shallow intervals beneath Northstar are not interpreted to be faulted. Seismic discontinuities from 2900' TVD to 6300' TVD are interpreted to be the artifact of rapid velocity changes and the probability of faults existing is Iow. If faults are encountered, the possibility of losses still exists. To be prepared for any potential lost circulation, a copy of the 'Recommended Lost Circulation Procedures' and the 'Lost Circulation Decision Tree' will be sent to the rig prior to drilling. · A fault is anticipated near the top of the Kingak formation at approximately 9855' MD / 9726' TVDrkb (+/-300' tvd). This fault was penetrated in the Seal A-02 and A-02a wells. Tight hole and sloughing were reported in the interval of the fault. A second fault will be in close proximity (-110') to the wellbore in the lower Kingak Shale at approximately 10609' md / 10406' TVDrkb. Losses are not anticipated but the lost circulation plan listed above will be in place on the rig. · Prior to drilling the Kingak shale, the mud system will be weighted up to 11.0 - 11.5 ppg. The increased mud weight is needed due to hole stability and not pore pressure. With the higher mud weight, differential sticking in the shallow sands may occur. The drill string will be kept moving as much as practical. Barofibre sweeps will be pumped to prevent seepage/losses and provide a wall cake to help minimize sticking. · Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control tool to make sure the well does not become underbalanced. · Differential sticking can be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable SV Sands. · Gas in the SAG is possible. Circulate as required. According to Geology, the top of the SAG is poor, not porous/permeable rock. This, along with the higher mud weight should minimize the gas in the top of the SAG. · Full returns were lost while weighting up the mud system from 11.3 ppg to 11.6 ppg on NS27. PWD indicated an on bottom ECD of 11.8 ppg when the losses occurred. The mud program will target a maximum mud weight of 11.3 ppg initially. ECD should be minimized to avoid losses. A casing running schedule will be provided to help reduce the chance of inducing losses. · The kick tolerance for the 12 1/4" open hole section would be 173 bbls assuming an influx from the Sag River interval at -10952' MD / 10721' TVD. This is a worst case scenario based on a 9.23 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the 13-3/8" shoe, and 11.0 ppg mud in the hole. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ., NS31 Permit to Drill PRODUCTION SECTION: · Mudloggers will be rigged up throughout the entire section. Gas in the Sag River or Ivishak will be circulated out as required. · The intermediate shoe will be drilled out with the 11.0 - 11.5 ppg mud. The mud will then be displaced with a 9.7 ppg drill-in fluid. · Differential sticking is not anticipated but the drill string should not be left stationary for any length of time. · Losses are not expected but calcium carbonate (CaCO3) will be maintained in the system. If losses occur, larger sweeps of CaCO3 will be pumped and the LCM Decision Tree will be in place on the rig. · The Ivishak is a conglomerate section. Directional control will be maintained with MWD surveys to minimize doglegs. · The well is not planned to penetrate the Lisburne limestone. On offset wells, losses have been encountered in the Lisburne. The project Geologist will be in charge of picking the base of the Ivishak and only rathole sufficient to bury the open hole logs will be drilled. However, if the Lisburne is penetrated, the LCM Decision Tree will be in place on the rig. · The kick tolerance for the 8-1/2" open hole section is infinite (due to the limited amount of open hole) assuming an influx from TD at -11563' MD / 11281' TVD. This is scenario based on a 9.23 ppg pore pressure gradient, a fracture gradient of 10.6 ppg at the 9-5/8" shoe, and 9.7 ppg mud in the hole. Disposal: · There will be no annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be processed in the Grind and Inject Facility on Nabors 33E and will be disposed of in the Northstar NS10 Class I Waste Disposal Well. · Fluid Handling: All Class I and Class II fluids will be processed by the Grind and Inject Facility on Nabors 33E and will be disposed of in the Northstar NS10 Class I Waste Disposal Well. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage NS31 Permit to Drill SUMMARY DRILLING OPERATIONS Pre-Riq Work: 1. Set 20" conductor and weld an ABB Vetco landing ring for the ABB Vetco Multibowl Wellhead on the conductor. 2. Install 7' x 7' cellar. Ri.q Operations: 1. MIRU Nabors 33E. 2. Nipple up and function test 21-1/4" diverter system. 3. MU 16" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3219' MD / 3216' TVD. The actual surface hole TD will be +/-150' TVD below the top of the SV6 marker. 4. Run 13-3/8", 68# surface casing. Cement the casing to surface in 2 stages using a stage tool at +/- 1600' MD. 5. ND diverter system and NU casing / tubing head. NU BOPE and test to 5000 psi. 6. MU 12-1/4" directional assembly with MWD/GR/RES/DEN/NEU/PWD and RIH to stage tool closing plug. Pressure test the casing to 1000 psi for 5 min. Drill plug and RIH to float collar. Test the 13-3/8" casing to 2500 psi for 30 min. 7. Drill out remaining cement. Drill 20' of new formation below 13-3/8" shoe and perform Leak Off Test. (FIT/LOT procedure on file with AOGCC). 8. Drill 12-1/4" intermediate hole to casing point at approximately 10952' MD / 10721' TVD (+/-20' into the Sag River). Note: EOB at +/- 8520' MD / 8490' TVD. Min mud wt. by top Kuparuk 9.8 ppg. 9. Run 9-5/8", 53.5# intermediate casing. Cement the casing to +/- 4049' MD (top SV2 sand) in a single stage. Perform a downsqueeze on the 9-5/8" x 13-3/8" annulus with 1 annular volume of mud immediately following the cement job. Downsqueeze diesel to 1800' MD for freeze protection after WOC. 10. Pack off the casing hanger. 11. MU 8-1/2" directional assembly with MWD/GR/RES/PWD and RIH to float collar. Pressure test the 9- 5/8" casing to 3000 psi for 30 min. 12. Drill out remaining cement. Drill 20' of new formation below 9-5/8" shoe with 11.0 - 11.5 ppg mud and perform a Formation Integrity test. (FIT/LOT procedure on file with AOGCC). Since the mud weight will be lowered to 9.7 ppg after the FIT, monitor the wellbore for 10 minutes. If no losses occur, displace with the 9.7 ppg drill-in fluid. 13. Drill 8-1/2" production 'tangent' interval to TD at approximately 11563' MD / 11281' TVD. 14. RU Schlumberger E-line unit and run open logs (GR/Res/Den/Neu/Sonic;RFT/NGT). Run USIT from the 9 5/8" shoe to confirm isolation within the Kingak. POOH and RD Schlumberger. 15. Make a clean out run if required and condition the hole for a liner. POOH. 16. Run and cement the 7" 29# 13Cr liner. Set the liner hanger and liner top packer. Circulate off any excess cement. 17. POOH with liner setting tool to +/- 1800' MD. 18. Displace the well to 9.7 NaCI brine (Brine weight = Mud weight) from 1800' to surface. Continue POOH and freeze protect from surface to 100' MD with mineral oil. 19. Pressure test well to 3200 psi for 30 minutes with a 9.7 ppg fluid to confirm liner integrity. 20. Land tubing hanger with 1 joint of 7" tubing below the hanger and TWC installed. 21. Nipple down the BOPE. Nipple up suspension cap (minimum of one valve and pressure gauge). 22. Rig down and move off suspended well. During batch completion operations: 23. MIRU Nabors 33E. 24. Check for pressure on the 9-5/8" casing. Bleed pressure as required. 25. Nipple down tree and NU BOPE. 26. Test BOPE to 5000 psi. Pull tubing hanger. 27. RIH with 6" cleanout assembly. Clean out to PBTD. RECEIVED Alaska Oil & Gas Cons. Cornr~-lission Anchorags · . NS31 Permit to Drill ('" 28. Displace well to 8.5 ppg seawater and monitor. POOH. 29. Run the 7", 29#, 13Cr NSCC completion assembly to the top of the 7" liner at +/-10802' MD. Run a SSSV at 2000' MD. 30. Land the tubing hanger. 31. Nipple down the BOPE. Nipple up and test the tree to 6500 psi. 32. Displace annulus with inhibited seawater and diesel FP to +/- 1800'. U-tube diesel to tbg. side. 33. Set the packer. Pressure test the tubing and annulus to 5500 psi for 30 minutes. 34. Install BPV. Rig down and move off. Post-Riq Work: 1. MIRU slickline. Pull the ball and rod / RHC profile from 'RN' nipple below the new production packer. 2. Perforate interval based on PE recommendation. Estimated Spud Date: 3/30/01 Andy Krieger Operations Drilling Engineer 564-5390 RECEIVED Alaska Oil & Gas Cons. Commissiol~ Anchorage NS31 Permit to Drill NS31 Ri site Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Gas hydrates may be present near the base of the permafrost. Mudloggers will be used continuously on NS31 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. Differential sticking could be problematic in both the surface and intermediate hole sections adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud, and string in Barofibre prior to penetrating sand intervals. Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indication of shallow gas was seen in NSIO or NS27. Mudloggers will be used continuously on NS31 to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. A minimum of 9.0 ppg is recommended. Severe losses have been seen in the intermediate section. Mud weight and ECD will be managed to reduce the risk of inducing losses. To be prepared for any potential lost circulation, a copy of the 'Recommended Lost Circulation Procedures' and the 'Lost Circulation Decision Tree' will be sent to the rig prior to drilling. Packing off due to improper hole cleaning can lead to stuck pipe. The PWD data, pick-up/slack-off weights and other drilling parameters must be monitored at all times. If in doubt, stop and condition the hole prior to drilling ahead or tripping. The Kingak shale, in the offset wells, experienced severe hole instability. The higher mud weight (11.0 - 11.5 ppg) and Iow angle (23.49 deg) will help with hole conditions. Conglomerate drilling in the Ivishak can lead to lost circulation, packing off due to unconsolidated formation and directional problems due to deflection of the drill string off of large rocks. Key drilling parameters must be monitored at all times. Do not drill ahead if a potential problem is detected. Northstar is not a designated H2S pad. CONSULT THE NORTHSTAR PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION RECEIVED MAR 1 6 7001 Alaska Oil & Gas Cons, Commission Anchorage TREE: ABB-VGI 7" 6.5 ksi NS31 ORIGINAL RT. ELEV = 55.77' WELLHEAD:ABB-VG, I'"' RT/GL. ELEV =40.2' 13-5/8" 6.5 ksi Multibowl -- --~ CB/MSL. ELEV = 15.67' [ ~~ --HRQ SSSV @2000' 7" HRQ SVLN 5.963" ID , I ~6.SPPG DIESEL FREEZE PROTECTION AT +/- 1800 I L-80, BTC (~3219' ' 7", 29#/ft, 13Cr TUBING ID: 6.184" CAPACITY: 0.037 BBL/FT 7" R NIPPLE, (~10752' 5.963" ID (OTIS) 7" R NIPPLE, @ 10782' ~;~ i~ ~ Baker SABL-3 PACKER 5.963" ID (OTIS) ~ I I 6.00" ID @10762' 7" RN NIPPLE, (~10792' ~ 5.77" ID (OTIS) 7" WLEG, (~10802' 6.184" ID (OTIS) 7" LINER TOP (~10802' 9 5/8", 53.5#/ft L-80, BTC-M ~10952' ~'~ · RECEIVED MAR 1 6 ZOO1 Alaska Oil & Gas Cons, Commission I Anchorage PBTD @11483' TD @11563' -- 7", 29#, 13Cr DATE REV. BY COMMENTS Northstar 3/15/01 AGK Initial Diagram WELL: NS31 APl NO: BP Exploration (Alaska) NS31 Proposed Well Profile - Geodetic Report Report Date: March 12, 2001 Client: BPXA Field: Northstar Structure I Slot: Northstar PF / NS31 Well: NS31 Approved Borehole: NS31 UWilAPD: 50-029- Survey Name I Date: NS31 (P4) / March 12, 2001 TortlAHDIDDI IERD ratio: 33.489° / 1499.91 ft/4.712 / 0.13,! Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Location LatJLong: N 70 29 29.647, W 14841 36.01(: Location Grid N/E Y/X: N 6031121.200 flUS, E 659822.100 flUS Grid Convergence Angle: +1.23167528° Grid Scale Factor: 0.99992902 o31t4 rot Survey I DL$ Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North .> True North: Local Coordinates Referenced To: Minimum Curvature / Lubinski 52.230° N 0.000 fi, E 0.000 fl KB 55.77 fl relative to MSL to REC E IVE D 26,807° 57489,585 nT MAR 1 6 2001 April 20, 2001 BGGM 2000 True Nodh Alaska 0il & Gas Cons. Commission +26,807° Anchorage Well Head Grid Coordinates Geographic Coordinates (f~) ¢) 1o) (f~) (f~) (f~) (ft) (Otl0~) iftus) iftus~ KB 0.00 0.00 90.00 0.00 0.00 0.00 0.00 0.00 6031121.20 659822.10 N 70 29 29.647 W 148 41 36.010 Bid 1/100 500.00 0.00 90.00 500.00 0.00 0.00 0.00 0.00 6031121.20 659822.10 N 70 29 29.647 W 148 41 36.010 600.00 1.00 90.00 599.99 0.69 0.00 0.87 1.00 6031121.22 659822.97 N 70 29 29.647 W 148 41 35.984 700.00 2.00 90.00 699.96 2.76 0.00 3.49 1.00 6031121.28 659825,59 N 70 29 29.647 W 148 41 35.907 800.00 3.00 90.00 799.86 6.21 0,00 7.85 1.00 6031121.37 659829.95 N 70 29 29,647 W 148 41 35.779 900.00 4.00 90.00 899.68 11.03 0.00 13.96 1.00 6031121.50 659836.06 End Bid 1000.00 5.00 90.00 999.37 17.23 0.00 21.80 1.00 6031121.67 659843.89 Top Permafrost 1207.19 5.00 90.00 1205.77 31.51 0.00 39.86 0.00 6031122.06 659861.95 Base Permafrost 1558.53 5.00 90.00 1555.77 55.71 0.00 70.48 0.00 6031122.71 659892.56 Drp 1/t00 1600.00 5.00 90.00 1597.08 58.57 0.00 74.10 0.00 6031122.79 659896.18 End Drp SV6 13-3/8" Csg Pt SV5 SV4 SV2 1700.00 4.00 90.00 1696.77 64.77 0.00 81.94 1.00 6031122.96 659904.02 1800.00 3.00 90.00 1796.59 69.60 0.00 88.05 1.00 6031123.09 659910.12 1900.00 2.00 90.00 1896.49 73.05 0.00 92.41 1.00 6031123.19 659914.48 2000.00 1.00 90.00 1996.45 75.12 0.00 95.03 1.00 6031123.24 659917.10 2100.00 0.00 90.00 2096,45 75.81 0.00 95.90 1.00 6031123.26 659917.97 3069.32 0.00 49.97 3065.77 75.81 0.00 95.90 0.00 6031123.26 659917.97 3219.32 0.00 49.97 3215.77 75.81 0.00 95.90 0.00 6031123.26 659917.97 3349.32 0.00 49.97 3345.77 75.81 0.00 95.90 0.00 6031123.26 659917.97 3649.32 0.00 49.97 3645.77 75.81 0.00 95.90 0.00 6031123.26 659917.97 4049.32 0.00 49.97 4045.77 75.81 0.00 95.90 0.00 6031123.26 659917.97 N 70 29 29.647 W 148 41 35.599 N 70 29 29.647 W 148 41 35.368 N 70 29 29.647 W 148 41 34.837 N 70 29 29.647 W 148 41 33.936 N 70 29 29.647 W 148 41 33.829 N 70 29 29.647 W 148 41 33.599 N 70 29 29.647 W 148 41 33.419 N 70 29 29.647 W 148 41 33.291 N 70 29 29.647 W 148 41 33.213 N 70 29 29.647 W 148 41 33.188 N 70 29 29.647 W 148 41 33.188 N 70 29 29.647 W 148 41 33.188 N 70 29 29.647 W 148 41 33.188 N 70 29 29.647 W 148 41 33.188 N 70 29 29.647 W 148 41 33.188 NS31 (P4) report,xls Page 1 of 2 3/14/2001-2:45 PM Grid Coordinates Geo~lraphic Coordinates (ft) (°) I°l (ftI (ft1 Iff) (ft) (°/lOOft) (flUS) fftUS~ SVl 4429.32 0.00 49.97 4425.77 75.81 0.00 95.90 0.00 6031123.26 659917.97 N 70 29 29.647 W 148 41 33.188 TMBK 4779.32 0.00 49.97 4775.77 75.81 0.00 95.90 0.00 6031123.26 659917.97 N 70 29 29.647 W 148 41 33.188 Top Schrader Bluff 6374.32 0.00 49.97 6370.77 75.81 0.00 95.90 0.00 6031123.26 659917.97 N 70 29 29.647 W 148 41 33.188 Top Colville 6944.32 0.00 49.97 6940.77 75.81 0.00 95.90 0.00 6031123.26 659917.97 N 70 29 29.647 W 148 41 33.188 KOP Bid 1/100 7500.00 0.00 49.97 7496.45 75.81 0.00 95.90 0.00 6031123.26 659917.97 N 70 29 29.647 W 148 41 33.188 Bid 2/100 Build 2.5/100 7600.00 1.00 49.97 7596.44 76.68 0.56 96.57 1.00 6031123.84 659918.63 7700.00 3.00 49.97 7696.38 80.16 2.81 99.24 2.00 6031126.14 659921.25 7800.00 5.50 49.90 7796.09 87.57 7.58 104.91 2.50 6031131.03 659926.82 7900.00 8.00 49.87 7895.39 99.31 15.15 113.90 2.50 6031138.79 659935.64 8000.00 10.50 49.86 7994.08 115.37 25.51 126.18 2,50 6031149.41 659947,69 N 70 29 29.653 W 148 41 33.168 N 70 29 29.675 W 148 41 33.090 N 70 29 29.722 W 148 41 32.923 N 70 29 29.796 W 148 41 32.658 N 70 29 29.898 W 148 41 32.297 8100.00 13.00 49.85 8091.98 135.72 38.64 141.75 2.50 6031162.87 659962,98 8200.00 15.50 49.84 8188.90 160.31 54.51 160.56 2.50 6031179.14 659981.44 8300.00 18.00 49.84 8284,65 189.10 73.10 182.58 2.50 6031198.20 660003.05 8400.00 20.50 49.83 8379.05 222.04 94.36 207.78 2.50 6031220.00 660027.79 8500.00 23.00 49.83 8471.92 259.06 118.26 236.09 2.50 6031244.50 660055.58 N 70 29 30.027 W148 41 31.839 N 70 29 30.183 W148 41 31.285 N 70 29 30.366 W148 41 30.637 N 70 29 30.575 W148 41 29.895 N 70 29 30.810 W148 41 29.062 End Bid 8519.57 23.49 49.83 8489.90 266.77 123.25 241.99 2.50 6031249.61 660061.37 Top HRZ 8607.74 23.49 49.83 8570.77 301.89 145.92 268.84 0.00 6031272.85 660087.72 Base HRZ 8694.97 23.49 49.83 8650.77 336.62 168.34 295.41 0.00 6031295.84 660113.80 Top Kupa~k 8771.30 23.49 49.83 8720.77 367.02 187.97 318.66 0.00 6031315.96 660136.62 Kuparuk C 8989.37 23.49 49.83 8920.77 453.86 244.04 385.07 0.00 6031373.44 660201.81 N 70 29 30.859 W148 41 28.889 N 70 29 31.082 W148 41 28.098 N 70 29 31.303 W148 41 27.317 N 70 29 31.496 W148 41 26.632 N 70 29 32.047 W148 41 24.678 LCU / Miluveach 9131.11 23.49 49.83 9050.77 510.31 280.48 428.24 0.00 6031410.80 660244.18 Top Kingak 9676.29 23.49 49.83 9550.77 727.41 420.65 594.28 0.00 6031554.50 660407.16 Top Sag River 10930.19 23.49 49.83 10700.77 1226.75 743.04 976.17 0.00 6031885.00 660782.00 Target 10930.19 23.49 49.83 10700.77 1226.75 743.04 976.17 0.00 6031885.00 660782.00 9-5/8" Csg Pt 10952.00 23.49 49.83 10720.77 1235.43 748.65 982.81 0.00 6031890.75 660788.52 N 70 29 32.406 W148 41 23.407 N 70 29 33.784 W148 41 18.521 N 70 29 36.954 W148 41 7.281 N 70 29 36.954 W148 41 7.281 N 70 29 37.009 W14841 7.085 Top Shublik 11039.23 23.49 49.83 10800.77 1270.17 771.08 1009.38 0.00 6031913.74 660814.60 Top Ivishak 11148.26 23.49 49.83 10900.77 1313.59 799.11 1042.58 0.00 6031942.48 660847.19 Top Kavik 11497.17 23.49 49.83 11220.77 1452.53 888.82 1148.85 0.00 6032034.44 660951.50 TD / 7" Lnr Pt 11562.60 23.49 49.83 11280.77 1478.59 905.64 1168.77 0.00 6032051.69 660971.05 N 70 29 37.230 W148 41 6.303 N 70 29 37.506 W14841 5.326 N 70 29 38.388 W14841 2.198 N702938.553 W148411.612 Legal Description: Surface: 1348 FSL 649 FELS11 T13N R13E UM Target: 2091 FSL 4952 FEL S12 T13N R13E UM BHL: 2254 FSL 4759 FEL S12 T13N R13E UM No~hinq~)rflus] Eastinq (X) 6031121.20 659822.10 6031885.00 660782.00 6032051.69 660971.05 rflus] RECEIVED 1 6 Z001 Alaska Oil & Gas Cons. Commission Anchorage NS31 (P4) report.xls Page 2 of 2 3/14/2001-2:45 PM Schlumberger 2000- ..c ~' 6000- ~ ~000 - 10000- 12000- Hpld Angle 2349° -4000 -2000 0 2000 4000 Vertical Section Departure at 52,23 deg from (0.0, 0.0). (1 in = 2000 feet) 0 200 400 600 / Schlumberger 800 1000 1200 ~C 1000 1200 0 200 400 600 800 ..... · ........ <<< WEST EAST H 181298 DATE 122100 PYMT HANDL INVOICE / CREDIT MEMO CK122100S ;OMMENTS: Pe~ NG INST: S/H THE AI'rACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. _ DESCRIPTION it to d~ill :ee - Sond~a X4'ZSO GRO~ 100.00 R Alaska Oil i812~8 VENDOR A..~LASKA[~ I LA O0 DISCOUNT NET --------- 100. O0 ~ ] t ~00~ Gas Cons. Gommissio' Anchomge No.H -1 F.i RsT:~'~TIO~E.:B AN i~::~F AS'HEAND ?:.;.~:.~-: '-;..=========================}.:-- 412 CoNsO.UDA:~.ED ~(~MM:~iRciA~_:ACCO'U'NT i::. ' O01812~8: PAy · , , , WELL PERMIT CHECKLIST COMPANY FIELD & POOL ,,~3"~'(::::~/' ~ 0 INIT CLASS WELL NAME,/~..~' .~' / PROGRAM: exp der ~ reddl ~ serv. wellbore seg ann. disposal para req ?- ~,? ' GEOL AREA ¢~'.~"' ~-,') ' UNIT# ,,/,,2,~ ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in ddlling unit ............ 8. If deviated, is wellbore plat included ............. ... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit canbe issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor stdng provided ................... 15. Surface casing protects all known USDWs ........... QATE 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. GEOLOGY 30. 31. 32. R A E 33. CMT vol adequate to circulate on conductor & surf csg ..... ~ N CMT vol adequate to tie-in long string to surf csg ........ Y CMT will cover all known productive horizons. ~ N Casing designs adequate for C, T, B & permafrost ....... (Y-'~ N - , -- Adequate tankage or reserve pit ................. ~ N ~_,~.~,\,,--.r.,.~"~ %. i ~,,~::~ ~"~e..~".....~. ~)\~ · If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ....... : ...... (~ N C.._~.c~.. c~ o~c~',¢__~,. ~._~_~',,~'~'~.~--'~ C..,~'q~.~,,..~ ~-..~ If diverter required, does it meet regulations .......... Drilling .fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ........ _.......... ~ N ~ ~ ~ ' " BOPE press rating appropriate; test to ,..~'~{:~r,~ psig. N ¥,tt~'~ ~'~,,'~-\~,.~ I~. ~ ¢o ~ ?~;~,.~, · . Choke manifold complies w/APl RP-53 (May 84) ......... ~ N . Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. Y k Permit can be issued wlo hydrogen sulfide measures ...... ~ N Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ........... , . Seabed condition survey (if off-shore) ............. .~' Y N ' Contact name/phone for weekly progress reports [exploratoc~only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... APPR DATE Y N Y N (B) will not contaminate freshwater; or cause ddlling waste to surface; ' (C) will not impair mechaniCal integrity of the well used for diSposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412~ Y N GEOLOGY: ENGINEERING: IJ[C.~/Annular COMMISSION: Comments/Instructions: c:~nsoffice\wordian~iana\checklist (rev. 11101//00)
