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201-086
Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/14/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NS-13 (PTD 201-086) Production Profile 08/05/2021 Please include current contact information if different from above. 37' (6HW Received By: 10/14/2021 By Abby Bell at 3:03 pm, Oct 14, 2021 STATE OF RECRIIED • ALAS OIL AND GAS CONSERVATION COMMI ON REPORT OF SUNDRY WELL OPERATIONS APR 0 3 2018 1.Operations Abandon LJ Plug Perforations U Fracture Stimulate U Pull Tubing U rl : g r�t own Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change 'pprove Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑ Exploratory ❑ 201-086 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic III Service ❑., 6.API Number: AK 99503 50-029-23017-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312799 NORTHSTAR UNIT NS-13 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A NORTHSTAR/NORTHSTAR OIL 11.Present Well Condition Summary: Total Depth measured 12,000 feet Plugs measured 11,634 feet true vertical 11,256 feet Junk measured N/A feet 9,900, 11,222& Effective Depth measured 11,634 feet Packer measured 11,276 feet 9,164, 10,479& true vertical 10,890 feet true vertical 10,533 feet Casing Length Size MD TVD Burst Collapse Conductor 161' 20" 161' 161' N/A N/A Surface 3,198' 13-3/8" 3,198' 3,178' 5,020psi 2,260psi Intermediate 10,083' 9-5/8" 10,083' 9,345' 6,870psi 4,760psi Liner 1,588' 7" 11,488' 10,745' 7,240psi 5,410psi Liner 699' 4-1/2" 11,975' 11,231' 8,430psi 7,500psi Perforation depth Measured depth See Schematic feet SCA14148 : 4t . True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13Cr/VAM-ACE 11,270' 10,527' 9-5/8 x 7"LT,7 x 4-1/2 Perm&7"5 Packers and SSSV(type,measured and true vertical depth) "LTP 4-1/2"HXO SVL Nipple See Above 1,997 MD/1,997 TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 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 1,344 3,974 Subsequent to operation: 0 0 0 1,105 95 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ElExploratory❑ Development Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ Q SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-046 Authorized Name: Bo York Contact Name: Wyatt Rivard MA Authorized Title: Operations Manager Contact Email: wrlyard(C7hilcorp.com —1-512672714(3 1- %893Authorized Signature: Date 8 Contact Phone: 777-8547 Form 10 101 ..cd 1/2017 Submit Original Only H . io Northstar Unit Well: NS-13 SCHEMATIC Last Completed: 12/02/2001 Ilikorp Alaska,LLC PTD: 201-086 Orig.KBE=56.19'/BFE=40.29'(CB 15.9') TREE&WELLHEAD Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI ,. .__ . .1:---, 20"a OPEN HOLE/CEMENT DETAIL 20" Driven 1 13-3/8" 140 sx"L",470 sx Class"G",1,853 sx PF"E",in 16"Hole 9-5/8" 68 sx Lite,400 sx Class"G",503 sx Econolite in 12-1/4"Hole 13 3/8" 7" 318 sx Class"G"in 8-1/2"Hole e 4-1/2" 97 sx Class"G"in 6-1/8"Hole CASING DETAIL 2 Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 169/X-56/N/A N/A Surface 201' N/A 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,198' 0.1497 9-5/8" Intermediate 47/L-80/Btrc. 8.681 Surface 10,083' 0.0732 7" Liner 26/L-80/BTC-M 6.276 9,900' 11,488' 0.0383 4-1/2" Liner 12.6/13Cr/Vam Ace 3.958 11,276' 11,975' 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr/Vam Ace 3.958 Surface 11,270' 0.0152 WELL INCLINATION DETAIL KOP @ 2,363' Max Hole Angle=31 deg.@ 6,354' I Max Angle at Top Perf:4 Deg.@ 11,724' JEWELRY DETAIL No Depth Item 1 1,997' 4-1/2"HXO SVL Nipple- ID=3.813" 2 5,161' CAMCO GLM w/RK latch ST1:Port=0,Dev=30,VIv=Dummy,TVD=4,910'-Set 11/28/2001 3 9,900' 9-5/8"x 7"Liner Top Packer and Hanger 4 11,178' 4-1/2"Cidra PT Gauge,ID=3.813" IL i15 11,200' 4-1/2"HES X Nipple,ID=3.813" "� i ,, 3 6 11,222' 7"x 4-1/2"Baker S-3 Perm Packer,ID=3.875" I . Is 7 11,246' 4-1/2"HES X Nipple,ID=3.813" 8 11,257' 4-1/2"HES XN Nipple,ID=3.800",milled 4/2/2013 9-5/8" 9 11,276' 7"x 5"Baker Liner Top Packer 4 10 11,269' 4-1/2"WLEG,ID=3.958"-Bottom @ 11,270' Ht ► 11 11,290' 7"x 5"Baker Liner Hanger two 6 12 . 11,299' 5"x 4-1/2"XO,ID=3.958" !' 6 ,---> 13 11,652' 4-1/2"CIBP w/Cement Cap @ 11,634' Mn 13.8"@ii 14 11,657' 45 KB Packer w/2-7/8"QCLL Stinger,10=2.441"(4/17/2014) 11,257',4-1/2"XN ) 15 11,663' 4-1/2"x 2-7/8"QCLL Swell Packer Patch,(6/03/2013)Bottom @ 11,866' A I16 11,864' 2-7/8"HES XN Nipple,ID=2.205" r �1 OP 16 DETAIL 9 P�`�- Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status '�L' J 10 11,724' 11,864' 10,980 11,120 140 12/01/2001 Closed&Sqzd _ ,11 / 11,755' 11,855' 11,011' 11,111 100 8/5 to 8/7/17 Closed TOC @ 11,608SLM - ;� �4 11,856' 11,874' 11,112 11,130 18 4/16/2007 Closed /67:1;.t. , Fis,•suckSLTod Ivishak 11,860' 11,886' 11,116 11,142 26 1/19/2005 Closed&Sgzd Stri ;,Top@ 11,874' 11,894' 11,130 11,150 20 4/08/2007 Closed 11': ' I �_�,13 11,880' 11,890' 11,136 11,146 10 4/01/2007 Closed r GENERAL WELL INFO P '. Ivishak API:50-029-23017-00 00 r:.`16 Completed-12/2/2001 TD@11,891'Tagged t,-' SAFETY NOTE 3/23/2014 i * Well requires a SSSV. 4-1/2"Chrome Tubing&Liner 4-1/2"* ',`£ TO=12,000'(MD)/TD=11,256'(TVD) PBTD=11,910'(MD)/PBTD=11,166'(TVD) Revised By:TDF 3/26/2018 • • z5 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-13 Slickline 50-029-23017-00-00 201-086 3/3/18 3/12/18 Daily Operations: 2/28/2018-Wednesday No activity to report. 3/1/2018-Thursday No activity to report. 3/2/2018-Friday No activity to report. 3/3/2018-Saturday WELL SHUT-IN ON ARRIVAL(pre RWO). PT PCE 250#-LOW/4,800#-HIGH. PULLED INTACT 4-1/2" MCX SSSV ON CARRIER (HM- 12) FROM HXO SVLN AT 1,960' SLM (1,997' MD). DRIFT TBG W/3.70" CENT.TO 45 KB PKR (QCLL)AT 11,633' SLM (11,657' MD). RAN 20'x3.00" DUMP BAILER TO TOP OF 45 KB PKR FILLED W/5 GALLONS OF WATER TO TOP OF KB PKR AT 11,633' SLM (11,657' MD). LRS LOADED UR W/600 BBLS SEAWATER(80 DEG F.) 3/4/2018-Sunday PT PCE 250#-LOW/4,800#-HIGH. LRS LOADED TBG W/& FREEZE PROTECTED. SET 4-1/2" HES CIBP @ 11,628' SLM W/HES DPU. LRS ATTEMPTED MIT-T(PRESSURE RISING DUE TO WING LEAKING OR THERMAL FROM FLUIDS). 1 , 3/5/2018- Monday No activity to report. 3/6/2018-Tuesday PT PCE 300#-LOW/4,500#-HIGH. PERFORMED PASSING MIT-T TO 2,000#ON CIBP (see log for details). RAN 20 'x 3.00" DUMP BAILER FILLED W/WATER TO TOP OF CIBP AT 11,628'SLM (no issues running in and sheared properly in fluid). MADE 1 RUN W/20' x 3.00" DUMP BAILER TO TOP OF CIBP AT 11,628'SLM (3.7 gallons of cement). • S • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-13 Slickline 50-029-23017-00-00 201-086 3/3/18 3/12/18 Daily Operations: 3/7/2018-Wednesday PT PCE 250#-LOW/4,500#-HIGH. MADE 2 SUCCESSFUL RUNS W/20'x3.00" DUMP BAILER FILLED W/CEMENT TO TOP OF CIBP AT 11,628' SLM (-7.34 gallons of cement). LAST RUN W/DUMP BAILER BROUGHT BACK APPROX^3 GALLONS OF CEMENT PARTIALLY SET UP LEAVING APPROX 1/2 GALLON IN HOLE. DRIFTED TBG W/3.70" G. RING TO 11,600' SLM (no obstructions). 3/8/2018-Thursday PT PCE 250#-LOW/4,500#-HIGH. DRIFT TBG W/3.70" G. RING TO RESTRICTION AT 11,601'SLM, UNABLE TO WORK PAST (possible cement stringer). MADE ASSORT OF RUNS W/ BAILERS &STAR BIT TO TRY AND WORK THRU CEMENT STRINGER. 3/9/2018- Friday PT PCE 250#-LOW/4,500#-HIGH. RAN 2.53" STAR BIT TO CEMENT AT 11,608' SLM, UNABLE TO WORK PAST. RAN 10'x 2.50" P. BAILER TO CEMENT AT 11,608' SLM,TOOLS BECAME STUCK AFTER 5 MIN. DROP CUTTER BAR (good cut-all the wire recovered). PULLED CUTTER BAR. 3/10/2018-Saturday GATHER FISHING EQUIP. FROM DEADHORSE & ENDICOTT.TEST WIRELINE VALVES. PREP UNIT FOR BRAIDED LINE JOB IN MORNING. 3/11/2018-Sunday PT PCE 250#-LOW/4,500#-HIGH. RIGGED UP BRAIDELINE EQUIPMENT. MADE 2 ATTEMPTS TO PULL S/L TOOLSTRING FROM 11,564' BLM (1 hour and 50 min. of jarring working up to 3500#). 3/12/2018- Monday PT PCE 250#-LOW/4,500#-HIGH. MADE 1 ATTEMPT TO PULL SLICKLINE TOOLSTRING FROM 11,564' BLM (slipped of after 3 of licks,skirt blown out and dogs pulled). DRIFT TBG W/3.70" CENT. FOR ELINE CUTTER TO 11,300' SLM (no obstructions). WELL LEFT SHUT-IN ON DEPARTURE, DSO NOTIFIED. 3/13/2018-Tuesday No activity to report. ®F T„it 41 THE STATE � ; Alaska Oil and Gas N 't�'���, ,..fALAsKA Conservation Commission 2 �+"- 333 West Seventh Avenue ITh GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ® ain: 907.279.1433 F ALAS"it" MFax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations ManagerSCAM) t Hilcorp Alaska, LLC •! 'Jif; 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Northstar Field,Northstar Oil Pool,NU NS-13 Permit to Drill Number: 201-086 Sundry Number: 318-046 Dear Mr. York: 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, C - Hollis S. French Chair DATED this ' day of February, 2018. • RESIAYV .q ' ., 1a :31 • • RECEIVED STATE OF ALASKA FEB 0 2 'O ALASKA OIL AND GAS CONSERVATION COMMISSION 1 l ) r f APPLICATION FOR SUNDRY APPROVALS AOG C 20 MC 25.280 1.Type of Request: Abandon ❑ Plug Perforations Q• Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill El Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 201-086 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ElService Q. 6.API Number: Anchorage Alaska 99503 50-029-23017-00-00` 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 458A Will planned perforations require a spacing exception? Yes ❑ No El NORTHSTAR UNIT NS-13 ' 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: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,000' • 11,256' • 11,915' 11,171' 4,063 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 161' 20" 161' 161' N/A N/A Surface 3,198' 13-3/8" 3,198' 3,178' 5,020psi 2,260psi Intermediate 10,083' 9-5/8" 10,083' 9,345' 6,870psi 4,760psi Liner 1,588' 7" 11,488' 10,745' 7,240psi 5,410psi Liner 699' 4-1/2" 11,975' 11,231' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" 12.6#/13Cr/VAM-ACE 11,270' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"x 7"LT,7"x 4-1/2"Perm&7"x 5"LTP 9,900(MD)/9,164(TVD),11,222(MD)/10,479(TVD)&11,276(MD)/10,533(TVD) and 4-1/2"MCX Injection Valve and 1,997 MD/1,997 TVD 12.Attachments: Proposal Summary El Wellbore schematic Q 13.Well Class after proposed work: • Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service Q ' 14.Estimated Date for 15.Well Status after proposed work: 2/15/2018 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG El GSTOR ❑ SPLUG ❑ Commission Representative: GINJ Q . Op Shutdown ❑ Abandoned El 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Wyatt Rivard .,✓ Fes.- b•+n Authorized Title: Operations Manager Contact Email: Wrivard cl hilCorp.com Contact Phone: 777-8547 Authorized Signature: Date: 2/2/2018 COMMISSION USE ONLY Conditions of approval: tify Commission so that a representative may witness Sundry Nyfnber: _ D (-tom Plug Integrity ❑nq1tBOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 1111 Other: (f f-►1Pv'rt s& v rlc,.e_e 4w. , 4afi—Gu-e- ...4— Lc. 4,1C 1 S, //Z.(s) Post Initial Injection MIT Req'd? Yes ❑ No ❑ . �/ / Spacing Exception Required? Yes No Subsequent Form Required: 0 -" I d t'"{ ' '..!S T 1 r APPROVED BY Z Approved by: 6tirac:c-----,\____ COMMISSIONER THE COMMISSION Date: /GIlig" ( 2-6 P4 RiG LSubmit Form and �i / Form 10-403 Revised 4/2017 Approved a licati0s2e date of approval. Attachments-ie Duplicate s Ivishak P&A • )t,i- - N`- r Well: NS 13 ?PI c PTD: 201-086 laAPI: 50-029-23017-00uornAlaska,LL, , , . IZ � Well Name: NS-13 API Number: 50-029-23017-00 Current Status: SI Rig: SL Estimated Start Date: Feb 15, 2018 Estimated Duration: 5 day Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 201-086 First Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907)947-9533 (M) AFE Number: Well EZ Required Yes Current Bottom Hole Pressure: 5,173 psi @ 11,100'TVDSS (Based on SBHPS on NS-13 4/13/17) Maximum Expected BHP: 5,173 psi @ 11,100'TVDSS (Based on SBHPS on NS-13 4/13/17) Max. Proposed Surface Pressure: 4063psi (Based on 0.1 psi/ft.gas gradient) Last SI WHP: 3984psi (Taken on 1/29/18) Min ID: 2.205" @ 11,864' 2-7/8"XN Nip In Swell Packer Patch Brief Well Summary: NS-13 is a recently converted Ivishak gas injector shut7in due to low injectivity and TxIA communication while under gas injection.The well is believed to be limited in the lower completion due to a 2-7/8" permanent swell packer patch across most of the perforations.An attempt to perforate the patch resulted in minimal improvement in injectivity. Passing MIT-lAs on 7/6/15 and 5/18/17 have confirmed production casing integrity. Going forward, a workover rig will be utilized to restore tubing integrity and recomplete uphole as a producer in the Kuparuk. Objective: Use slickline to set a plug above the Ivishak perforations and dump bail cement to complete , plugback of the Ivishak in preparation for RWO. ***Variance Request*** 20 AAC 25.112(c)(1)(E) requires a bridge plug be set no more than 50' above the top of the perforated interval. Currently the top of the Ivishak perforations is 11,724' MD, however a leaking 2-7/8" permanent swell packer 0- -patch extends up to 11,657' MD.The CIBP will be set with slickline 5' above the top of the patch at^'11,652'MD or 72' MD above the perforated interval.The top of the Ivishak extends to 11,650' MD.The 25' cement plug will straddle the top of Ivishak sand and will ensure confinement of reservoir fluids in the Ivishak. Sundry Procedure (Approval Required to Proceed): Slickline & Hot Oil 1. RU SL unit and pressure test to 300psi low/4500 psi high. 2. RIH and pull 4-1/2" MCX set at 1960' 3. MU 4-1/2" CIBP Drift. a. KB packer/stinger assembly minimum ID is 2.441" 4. RIH and drift to top of KB packer at 11,657' 5. Correct depth to KB packer, POOH 6. Rig up LRS unit to 500 bbl Upright tank prefilled with at least 400 bbls ambient seawater 7. Roll tanks while heating seawater until heated to at least^'70 degF. • . Ivishak P&A Well: NS-13 PTD: 201-086 1hlcorp Alaska,LL API: 50-029-23017-00 8. MU 4-1/2" CIBP and setting tool and hold in lubricator 9. Rig up hardline from LRS skid to Pump In Sub and pressure test to 300psi low/4500psi high. 10. Begin to pump hot seawater from upright tank into the well at max rate until at least 300 bbls away. a. Wellbore volume of 4-1/2 tubing and liner is (.0152 bpf* 11,900' =± 180 bbls) b. Seawater heated to at least 70degF needed to minimize contraction forces on tubing 11. Once 300 bbls away, decrease pump rate to—.5-1BPM to maintain fluid pack 12. RIH with 4-1/2" CIBP 13. Swap pumping to diesel when SL is roughly 30 min off bottom. 14. Shut down pumps once tubing freeze protected to± 1600' (At least 25 bbls diesel) 15. SL stop at 11,500' if hot oil still pumping freeze protect. a. Do not tag KB packer if still pumping 16. Once freeze protected, continue to RIH and tag KB packer at 11,657'. 17. Pickup 5' and set 4-1/2" CIBP at± 11,652' a. This places the CIBP Mid Element in the lower third of a full 40 ft 4-1/2" Liner Joint 18. Following set,tag CIBP to confirm. POOH _ 19. MIT-T to 2000 psi for 30 minutes. / a. Previous slow TxIA communication only to gas with high differential. MIT-T should_pass to fluid./ If IA observed tracking, switch to CMIT-TxIA to 2000 psi to confirm plug set. 20. RDMO Hot Oil 21. Following good MIT, dump bail minimum of 25' of cement onto plug a. 4-1/2"Tubing volume of 2.184 gpf should require at least 55 gallons of cement b. BHT is 250 degF for cement blend 22. Drift for 4-1/2"jet cutter following cementing 23. Verify with final tag that Top of Cement is at least 25' above plug at±11,627' 24. RDMO SL. Attachments: Proposed Schematic/Well Schematic aJ d H . • Northstar Unit Well: NS-13 SCHEMATIC Last Completed: 12/02/2001 flilcorp Alaska,LLC PTD: 201-086 Orig.KBE=56.19'/BFE=40.29'(CB 15.9') TREE&WELLHEAD Tree ABB-VGI 5-1/8"5KSI ( ' Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 20" j OPEN HOLE/CEMENT DETAIL 20" Driven 11 i 1 13-3/8" 140 sx"L",470 sx Class"G",1,853 sx PF"E",in 16"Hole ! I9-5/8" 68 sx Lite,400 sx Class"G",503 sx Econolite in 12-1/4"Hole 133/8" j' t 7" 318 sx Class"G"in 8-1/2"Hole 4-1/2" 97 sx Class"G'in 6-1/8"Hole CASING DETAIL 2 . Size Type Wt/Grade/Conn ID Top Btm BPF 7 20" Conductor 169/X-56/N/A N/A Surface 201' N/A 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,198' 0.1497 1. 9-5/8" Intermediate 47/L-80/Btrc. 8.681 Surface 10,083' 0.0732 7" Liner 26/L-80/BTC-M 6.276 9,900' 11,488' 0.0383 1 z 4-1/2" Liner 12.6/13Cr/Vam Ace 3.958 11,276' 11,975' 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr/Vam Ace 3.958 Surface 11,270' 0.0152 WELL INCLINATION DETAIL KOP @ 2,363' Max Hole Angle=31 deg.@ 6,354' Max Angle at Top Perf:4 Deg.@ 11,724' JEWELRY DETAIL No Depth Item 1 1,997' 4-1/2"MCX Injection Valve w/HXO SVL Nipple- ID=3.813" - - 2 5,161' CAMCO GLM w/RK latch ST1:Port=0,Dev=30,Vlv=Dummy,TVD=4,910'-Set 11/28/2001 3 9,900' 9-5/8"x 7"Liner Top Packer and Hanger 4 11,178' 4-1/2"Cidra PT Gauge,ID=3.813" IL 3 5 11,200' 4-1/2"HES X Nipple,ID=3.813" 6 11,222' 7"x 4-1/2"Baker S-3 Perm Packer,ID=3.875" :II 7 11,246' 4-1/2"HES X Nipple,ID=3.813" 8 11,257' 4-1/2"HES XN Nipple,ID=3.800",milled 4/2/2013 9-5/8"A & 9 11,276' 7"x 5"Baker Liner Top Packer iitSe 4 10 11,269' 4-1/2"WLEG,ID=3.958"-Bottom @ 11,270' 11 11,290' 7"x 5"Baker Liner Hanger En 5 12 11,299' 5"x 4-1/2"XO,ID=3.958" 4 i,�; 6 13 11,657' 45 KB Packer w/2-7/8"QCLL Stinger,ID=2.441"(4/17/2014) 4 414 11,663' 4-1/2"x 2-7/8"QCLL Swell Packer Patch,(6/03/2013)Bottom @ 11,866' 7 15 11,864' 2-7/8"HES XN Nipple,ID=2.205" 4 PERFORATION DETAIL 8 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status IL= Al s 11,724' 11,864' 10,980 11,120 140 12/01/2001 Closed&Sqzd 10 11,755' 11,855' 11,011' 11,111 100 8/5 to 8/7/17 Open 11 11,856' 11,874' 11,112 11,130 18 4/16/2007 Closed 44 12 Ivishak 11,860' 11,886' 11,116 11,142 26 1/19/2005 Closed&Sqzd il. k 11,874' 11,894' 11,130 11,150 20 4/08/2007 Open y. , 11,880' 11,890' 11,136 11,146 10 4/01/2007 Open + � '13MnID 2.205"@ 4X14 GENERAL WELL INFO 11,864',2-7/8 XN API:50-029-23017-00-00 't Completed-12/2/2001 1 i 15 Ivishak ;1 , SAFETY NOTE @320 .77 TD 14 Well requires a SSSV. 4-1/2"Chrome Tubing&Liner 41/2"` T TD=12,000'(MD)/TD=11,256'(WD) PBTD=11,910'(MD)/PBTD=11,166'(TVD) Revised By:TDF 8/21/2017 • Northstar Unit II • Well: NS-13 PROPOSED Last Completed: 12/02/2001 Hhlcorp Alaska,LLC PTD: 201-086 Orig.KBE=56.19'/BFE=40.29'(CB15.9') TREE&WELLHEAD Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 20" OPEN HOLE/CEMENT DETAIL i 1 (1+--�+ 20" Driven L '' 1 13-3/8" 140 sx"L",470 sx Class"G",1,853 sx PF"E",in 16"Hole 9-5/8" 68 sx Lite,400 sx Class"G",503 sx Econolite in 12-1/4"Hole 13-3/8" 7" 318 sx Class"G"in 8-1/2"Hole 4-1/2" 97 sx Class"G"in 6-1/8"Hole 2 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 169/X-56/N/A N/A Surface 201' N/A 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,198' 0.1497 9-5/8" Intermediate 47/L-80/Btrc. 8.681 Surface 10,083' 0.0732 7" Liner 26/L-80/BTC-M 6.276 9,900' 11,488' 0.0383 4-1/2" Liner 12.6/13Cr/Vam Ace 3.958 11,276' 11,975' 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr/Vam Ace 3.958 Surface 11,270' 0.0152 WELL INCLINATION DETAIL KOP @ 2,363' Max Hole Angle=31 deg.@ 6,354' • Max Angle at Top Perf:4 Deg.@ 11,724' JEWELRY DETAIL No Depth Item 1 1,997' 4-1/2"MCX Injection Valve w/HXO SVL Nipple- ID=3.813" 2 5,161' CAMCO GLM w/RK latch ST1:Port=0,Dev=30,VIv=Dummy,TVD=4,910'-Set 11/28/2001 3 9,900' 9-5/8"x 7"Liner Top Packer and Hanger 4 11,178' 4-1/2"Cidra PT Gauge,ID=3.813" I` JI5 11,200' 4-1/2"HES X Nipple,ID=3.813" 3 6 11,222' 7"x 4-1/2"Baker S-3 Perm Packer,ID=3.875" b �iIv., 7 11,246' 4-1/2"HES X Nipple,ID=3.813" 8 11,257' 4-1/2"HES XN Nipple,ID=3.800",milled 4/2/2013 - 9-5/8" 9 11,276' 7"x 5"Baker Liner Top Packer Aiisz 4 10 11,269' 4-1/2"WLEG,ID=3.958"-Bottom @ 11,270' , 11 11,290' 7"x 5"Baker Liner Hanger tni 5 $ 12 11,299' 5"x 4-1/2"XO,ID=3.958" 0 � 6 13 ±11,627' TOC Mn ID 3.8"@ (,y' 4 14 ±11,652' 4-1/2"CIBP - 11,257',41/2"XN 15 11,657' 45 KB Packer w/2-7/8"QCLL Stinger,ID=2.441"(4/17/2014) 4 djK 16 11,663' 4-1/2"x 2-7/8"QCLL Swell Packer Patch,(6/03/2013)Bottom @ 11,866' it it 17 11,864' 2-7/8"HES XN Nipple,ID=2.205" M . L' `J 9 PERFORATION DETAIL t10i 11 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 12 ?ve- ,,iy 11,724' • 11,864' 10,980 11,120 140 12/01/2001 Closed&Sqzd"V 11,755' • 11,855' 11,011' 11,111 100 8/5 to 8/7/17 Closed ,1el Ivishak 11,856' 11,874' 11,112 11,130 18 4/16/2007 Closed 1' 11,860' • 11,886' 11,116 11,142 26 1/19/2005 Closed&Sqzd �;1 i 15 11,874' • 11,894' 11,130 11,150 20 4/08/2007 Closed b :a 11,880' 11,890' 11,136 11,146 10 4/01/2007 Closed 5 1� ty 1: 17 Ivishak GENERAL WELL INFO •:' API:50-029-23017-00-00 TD @ 11,891'Tagged Completed-12/2/2001 3/23/2014 y 41/2" SAFETY NOTE Well requires a SSSV. 4-1/2"Chrome Tubing&Liner TD=12,000'(MD)/TD=11,256'(TVD) PBTD=11,910'(MD)/PBTD=11,166'(WD) Revised By:TDF 1/25/2018 • Lot-iretg-- Seth Nolan Hilcorp Alaska, LLC 2 O s� GeoTech 3800 Centerpoint Drive, Suite 100 RECEIVED Anchorage, AK 99503 Tele: 907 777-8308 Tfilriwp Alaska,f.f.S: Fax: 907 777-8510 AUG 2 9 2017 E-mail: snolan@hilcorp.com DATE 08/24/17 AOGCC DATA LOGGED 9/S/2011 To: Alaska Oil & Gas Conservation Commission M. K.BENDER Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL '3 Prints: PERFORATION RECORD CD 1: AN Hikorp NS-13 PERF 07AUG 17 FINAL 8/24/2017 4:16 PM File folder Please include current contact information if different from above. SuttillED SEP 1 2 2017, Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By:/'^^�� (../, V�/`date: STATE OF ALASKA ALI/A OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑., Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development❑ Exploratory❑ 201-086 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service 2 6.API Number: AK 99503 50-029-23017-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312799 NORTHSTAR UNIT NS-13 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A NORTHSTAR/ NORTHSTAR OIL 11.Present Well Condition Summary: Total Depth measured 12,000 feet Plugs measured N/A feet true vertical 11,256 feet Junk measured N/A I 9,900, 11,222& Effective Depth measured 11,915 feet Packer measured 11,276 feet AUG 2 2 2017 9,164, 10,479& true vertical 11,171 feet true vertical 10,533 feet a l.� CC Casing Length Size MD TVD Burst Collapse Conductor 161' 20" 161' 161' N/A N/A Surface 3,198' 13-3/8" 3,198' 3,178' 5,020psi 2,260psi Intermediate 10,083' 9-5/8" 10,083' 9,345' 6,870psi 4,760psi Liner 1,588' 7" 11,488' 10,745' 7,240psi 5,410psi Liner 699' 4-1/2" 11,975' 11,231' 8,430psi 7,500psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13Cr/VAM-ACE 11,270' 10,527' 9-5/8 x 7"LT,7 x 4-1/2 Perm&7"5 Packers and SSSV(type,measured and true vertical depth) "LTP 4-1/2"MCX Injection Valve See Above 1,997 MD/1,997 TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 21,902 0 927 4,702 Subsequent to operation: 0 24,520 0 1,753 4,646 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ 0 SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-308 Authorized Name: Bo York Contact Name: Wyatt Rivard t,',tLIZ. Authorized Title: Operations Manager Contact Email: wrivardhiIcorp.com r// -2' • Authorized Signature: Dab 8/21/2017 Contact Phone: 777-8547 Form 10-404 Revised 4/2017 14,, 1 II,"I'7 RBDMS „� An' 2 5 2017 Submit Original Only H . • Norll:thstarNS-13 Unit .ini We SCHEMATIC Last Completed: 12/02/2001 ITileorp AIaeka,LLC PTD: 201-086 TREE&WELLHEAD Orig.KBE=56.19'/BFE=40.29'(CB 15.9') Tree ABB-VGI 5-1/8"SKS! Wellhead ABB-VGI 13-5/8"Multibowl SKSI 20"i 1 OPEN HOLE/CEMENT DETAIL A___,, 20" Driven L 13-3/8" 140 sx"L",470 sx Class"G",1,853 sx PF"E",in 16"Hole 9-5/8" 68 sx Lite,400 sx Class"G",503 sx Econolite in 12-1/4"Hole 13-3/8" • 7" 318 sx Class"G"in 8-1/r Hole ) 4-1/2" 97 sx Class"G"in 6-1/8"Hole CASING DETAIL 2 Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 169/X-56/N/A N/A Surface 201' N/A 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,198' 0.1497 9-5/8" Intermediate 47/L-80/Btrc. 8.681 Surface 10,083' 0.0732 7" Liner 26/L-80/BTC-M 6.276 9,900' 11,488' 0.0383 4-1/2" Liner 12.6/13Cr/Vam Ace 3.958 11,276' 11,975' 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr/Vam Ace 3.958 Surface 11,270' 0.0152 WELL INCLINATION DETAIL !; - KOP @ 2,363' Max Hole Angle=31 deg.@ 6,354' , Max Angle at Top Perf:4 Deg.@ 11,724' JEWELRY DETAIL No Depth Item 1 1,997' 4-1/2"MCX Injection Valve w/HXO SVL Nipple- ID=3.813" 2 5,161' CAMCO GLM w/RK latch ST1:Port=0,Dev=30,VIv=Dummy,TVD=4,910'-Set 11/28/2001 3 9,900' 9-5/8"x 7"Liner Top Packer and Hanger 4 11,178' 4-1/2"Cidra PT Gauge,ID=3.813" I` 3 5 11,200' 4-1/2"HES X Nipple,ID=3.813" j 6 11,222' 7"x 4-1/2"Baker S-3 Perm Packer,ID=3.875" 7 11,246' 4-1/r HES X Nipple,ID=3.813" 8 11,257' 4-1/r HES XN Nipple,ID=3.800",milled 4/2/2013 9-5/8"A _ • 9 11,276' 7"x 5"Baker Liner Top Packer Mr 4 10 11,269' 4-1/2"WLEG,ID=3.958"-Bottom @ 11,270' 41 11 11,290' 7"x 5"Baker Liner Hanger --;r 5 12 11,299' 5"x 4-1/2"X0,ID=3.958" ii M *I.* 6 13 11,657' 45 KB Packer w/2-7/8"QCLL Stinger,ID=2.441"(4/17/2014) 14 11,663' 4-1/2"x 2-7/8"QCLL Swell Packer Patch,(6/03/2013)Bottom @ 11,866' I IR 7 15 11,864' 2-7/8"HES XN Nipple,ID=2.205" PERFORATION DETAIL 8 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 11,724' 11,864' 10,980 11,120 140 12/01/2001 Closed&Sqzd L J' 10 11,755' 11,855' 11,011' 11,111 100 8/5 to 8/7/17 Open 11 11,856' 11,874' 11,112 11,130 18 4/16/2007 Closed b 12 Ivishak 11,860' 11,886' 11,116 11,142 26 1/19/2005 Closed&Sqzd 44 11,874' 11,894' 11,130 11,150 20 4/08/2007 Open 11880' 11,890' 11136 11,146 10 4/01/2007 Open e 13 MnlD=2.205"@ ?: 14 GENERAL WELL INFO 11,864',2-7/8"XN API:50-029-23017-00-00 'ti'_ 15 Ivishak Completed-12/2/2001 i< SAFETY NOTE TD @ 11,891'Tagged Well requires a SSSV. 4-1/2"Chrome Tubing&Liner 3/23/2014 L 4-1/Z' 1,;:r: TD=12,000'(MD)/TD=11,256'(TVD) PBTD=11,910'(MD)/PBTD=11,166'(TVD) Revised By:TDF 8/21/2017 • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-13 Slick Line 50-029-23017-00-00 201-086 7/28/17 8/8/17 Daily Operations: 7/26/2017 -Wednesday No activity to report. 7/27/2017 -Thursday No activity to report. 7/28/2017 - Friday PREP TOOL AND UNIT FOR JOB. ATP MEETING IN CONTROL ROOM, PJSM. BEGIN R/U,TOOL STRING= 15' 1-1/2" STEM, OJ'S, LSS. PT 250/4,050 PSI, RIH W/4.5" GS (STEEL), 60" PRONG SIT DOWN AND LATCH UP TO MCX @ 1,975' SLM (1,997' MD). HIT TWO 800#OJ LICKS AND TOOLS FREE, GAIN 50#, POOH. OOH W/TOOLS, SIBO. HAVE THE MCX. SSV LEAKING OUT OF THE BOLTS ON TREE. GREASE THE SSV. SWAP TOOL STRING= 15' 1-1/2" STEM, 1-1/2" OJ'S, LSS. RIH W/21' 2.0" BAILER, DRIFT AND TAG BOTTOM @ 11,864' SLM (11,884' MD/CORRECTED DEPTH), NO RESTRICTIONS DOWN TO TD, POOH. OOH W/TOOLS, SIBO. BEGIN R/D, SECURE WELL. 7/29/2017 -Saturday No activity to report. 7/30/2017-Sunday No activity to report. 7/31/2017- Monday No activity to report. 8/1/2017 -Tuesday No activity to report. • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-13 E-Line 50-029-23017-00-00 201-086 7/28/17 8/8/17 Daily Operations: 8/2/2017 -Wednesday No activity to report. 8/3/2017 -Thursday No activity to report. 8/4/2017 - Friday No activity to report. 8/5/2017-Saturday WELL S/I ON ARRIVAL(Eline adperf). LPT 250 PSI. HPT 4,200 PSI. RIH W/2" HSD LOADED 20'. OAL=42'. OD=2.21".TAG TD @ 11,890'. PERFORATE INTERVAL 11,835'-11,855'. CORRELATED TO SLB PACKER SETTING RECORD DATED 27-MAY-2013. WELL LEFT S/I. LAY DOWN OVER NIGHT. 8/6/2017 -Sunday LPT 250 PSI. HPT 4200 PSI. MADE THREE GUN RUNS W/2" HSD LOADED 20' EACH. PERFORATE INTERVAL 11,775' - 11,835' - ALL LOGS CORRELATED TO SLB PACKER SETTING RECORD DATED 27-MAY-2013. PERFORM WELL CONTROL DRILL. WELL LEFT S/I - LAY DOWN FOR NIGHT. 8/7/2017 - Monday LPT 250 PSI. HPT 4,200 PSI. RIH W/ FIFTH AND FINAL GUN 2" HSD LOADED 20' & PERFORATE INTERVAL 11,755' - 11,775'. CORRELATED TO SLB PACKER SETTING RECORD DATED 27-MAY-2013. 8/8/2017 -Tuesday PT PCE 250#-LOW/4,800#-HIGH. SET 4-1/2" MCX SSSV ON CARRIER (ser#HM-12) IN HXO SVLN AT 1,960' SLM (1,997' MD) (1.56" Bean). (1 piece of oversized pkg on each side of oversized o-ring on btm stack, std pkg w/oversize o-ring on top set). PERFORMED SUCCESFUL DRAWDOWN TEST ON MCX. WELL LEFT SHUT-IN ON DEPARTURE, DSO NOTIFIED. • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Saturday,August 19, 2017 10:34 PM To: Wallace, Chris D (DOA) Subject: RE: NS-13 (PTD#2010860) Monitoring Results Attachments: NS-13 TIO.xlsx Chris, Northstar gas injector NS-13 (PTD#2010860) returned to injection on 8/10/17 for a 28 monitoring period following resetting of a downhole injection valve. Following warmup of the well, IA pressure appeared stable at 1800 psi but a subsequent bleed on 8/15/17 resulted in repressurization to 1800 psi within 3 days. Pressurization of roughly 300 psi/day represents an increase over the build up rate observed prior to resetting the valve.The well has been shut-in and will remain shut-in until additional diagnostics are performed and integrity is restored. A TIO plot is attached for reference. Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED AUG 2 3 2017 From:Wyatt Rivard Sent:Thursday, August 10, 2017 4:05 PM To: 'Wallace,Chris D(DOA)'<chris.wallace@alaska.gov> Subject: RE: NS-13 (PTD#2010860) Request to Return to Injection Chris, Thank you for the approval. Slickline was successful in resetting the downhole valve and isolating/verifying the subsurface control line.The well is back on injection, monitoring results will be provided at 28 days with the well shut-in at any indication of further TxIA communication. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 From: . . - Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Monday,Au:. 17,2017 9:38 PM To:Wyatt Rivard<wrivard@ ..com> Subject: RE: NS-13 (PTD#2010860) Req• - . Return to Injection Wyatt, Plan as detailed below and discussed via phone today is acceptable. Regards, 1 • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday, August 7, 2017 9:38 PM To: Wyatt Rivard Subject: RE: NS-13 (PTD#2010860) Request to Return to Injection Wyatt, Plan as detailed below and discussed via phone today is acceptable. Regards, Chris SCANNED ` ' 2 nr,, .. Original message From:Wyatt Rivard<wrivard@hilcorp.com> Date:08/07/2017 3:56 PM (GMT-09:00) To: "Wallace,Chris D(DOA)" <chris.wallace@alaska.gov> Subject: NS-13 (PTD#2010860) Request to Return to Injection Chris, Northstar Gas injector NS-13 (PTD#2010860)was shut-in on 7/26/17 for possible TxIA communication. Following shut- in of the well,the IA pressure has remained relatively flat.With a 3000 psi differential between tubing and IA,the IA gained only 18 psi in 8 days. A TIO plot is attached for reference. Initial diagnostics found gas in the subsurface safety valve control line.When the control line was bled, it slowly pressurized back to tubing pressure, suggest possible communication past one of the seals on the downhole injection valve and through the unused control line. On 7/28/17,the 4.5" MCX valve was pulled in support of previously planned perforations(Sundry 317-308). Perforations were completed successfully and the well is ready to have the injection valve reinstalled. Hilcorp would like to bring the well back on injection briefly(12 hrs)to warmup the well prior to installing the injection valve to give it the best chance of a successful set. Once the valve is set,the control line will be purged with hydraulic fluid and bled down to verify isolation at the downhole valve.Once isolation is verified, Hilcorp would like to put the well back on injection for a 28 day monitoring period to verify integrity. Monitoring results would be provided at 28 days with the well shut-in at any indication of further TxIA communication. Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivardahilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 1 0 • . . .. LiOZ/LO/80 - LaoZ/50/80 - L10Z/£0/80 - LIOZ/t0/80 - LIOZ/0£/L0 4'_ LtOZ/8Z/L0 - LIOZ/9Z/L0 - LTOZ/ZZ/L0 0 - LIOZ/OZ/L0 �? - LIOZ/8t/L0 - LIOZ/9t/L0 - LIOZ/171/LO ...... ` LIOZ/Zt/L0 LIOZ/Ot/L0 -- LtOZ/80/LO -- LtOZ/90/L0 LIOZ/VO/L0 < E O/L0 O£/90 I Z/90 F._ ��� - LtOZ/9Z/90 _p LtOZ/bZ/90 F— • LIOZ/ZZ/90 m LIOZ/OZ/90 N (----....................................Z LIOZ/81/90 L[OZ/91/90 LIOZ/bt/90 Q t LIOZ/ZI/90 I LIOZ/Ot/90 LIOZ/80/90 LIOZ/90/90 LIOZ/b0/90 im... LIOZ/Z0/90 LIOZ/t£/S0 LtOZ/6Z/S0 Z.?LIOZ/LZ/S0 .a� LIOZ/SZ/S0 LIOZ/£Z/S0 I LIOZ/tZ/SO LIOZ/6t/S0 LIOZ/Lt/S0 LIOZ/St/S0 „., LTOZ/£t/S0 LIOZ/tt/S0 L1OZ/60/S0 0 0 0 0 0 0 0 0 0 0 0 00 0 00 0 00 0 00 0 00 0 vi- V V m rn N N .--I .--i aanssaad • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday,July 26, 2017 4:06 PM To: Wallace, Chris D (DOA) Subject: Gas Injector NS-13 (PTD#2010860) Shut-In For Possible TxIA communication Attachments: NS-13 TIO.xlsx Chris, Recently converted Northstar gas injector NS-13 (PTD#2010860) began injection on 5/13/17.The well had a passing AOGCC witnessed MIT-IA to 2700 psi on 5/18/17. Following the MIT,the well was bled once on 6/22/17 due to high injection temps and then again on 7/24/17.Since the 7/24/17 bleed, ambient temperatures have remained stable but the IA appears to be increasing at roughly 70 psi/day suggesting possible TxIA communication.A TIO plot is attached for reference. The well was SI today and will remain SI until diagnostics are complete and integrity restored.The well operates with a downhole injection check valve but retains the SSSV control lines from its initial completion as a producer.The control line pressure was checked today at 4200 psi, suggesting communication with the tubing and a possible leak path for the IA. Initial diagnostics will focus on verifying or restoring control line integrity. Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard(thilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED A Lt r, 0 9 20i? • • OF Tkt THE STATE Alaska Oil and Gas ofA LASKA Conservati®n Commissi®n 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ;SSP Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Northstar Field,Northstar Oil Pool,NS-13 Permit to Drill Number: 201-086 Sundry Number: 317-308 Dear Mr. York: 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, Hollis S. French Chair DATED this day of July, 2017. RBDMS I, JUL 1 1 2017 • 0 RECEIVED STATE OF ALASKA J(jf 0 6 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION GC APPLICATION FOR SUNDRY APPROVALS AOC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑, • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 201-086 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic El Service El. 6.API Number: Anchorage Alaska 99503 50-029-23017-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 458A Will planned perforations require a spacing exception? Yes ❑ No 2 NORTHSTAR UNIT NS-13 • 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: I Effective Depth TVD: MPSP(psi): 1 Plugs(MD): Junk(MD): 12,000' • 11,256' • 11,915' 11,171' 4,014 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 161' 20" 161' 161' N/A N/A Surface 3,198' 13-3/8" 3,198' 3,178' 5,020psi 2,260psi Intermediate 10,083' 9-5/8" 10,083' 9,345' 6,870psi 4,760psi Liner 1,588' 7" 11,488' 10,745' 7,240psi 5,410psi Liner 699' 4-1/2" 11,975' 11,231' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" 12.6#/13Cr/VAM-ACE 11,270' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"x 7"LT,7"x 4-1/2"Perm&7"x 5"LTP 9,900(MD)/9,164(TVD), 11,222(MD)/10,479(TVD)&11,276(MD)/10,533(TVD) and 4-1/2"MCX Injection Valve and 1,997 MD/1,997 TVD 12.Attachments: Proposal Summary ❑l Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑., 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 7/20/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑✓ • Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Wyatt Rivard Authorized Title: Operations Manager Contact Email: wrivard anhiIcorp.Com 4�27,PN � ,} Contact Phone: 777-8547 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 \7- 305‘ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance El Other: Post Initial Injection MIT Req'd? Yes El No ❑ RBDMS 7 Spacing Exception Required? Yes ❑ No f Subsequent Form Required: k u "— 4� JUL 1 1 207/ APPROVED BY Approved by: j-.411). J COMMISSIONER THE COMMISSION Date: 3 Fq I(q \` 14(31,21 "1 h in Submit Form and �1D-403 Revised 4/2017 0 Rilr V f 1 ' avalid for 12 months from the date of approval. Attachm nts in Duplicate • RePerf Well: NS-13 PTD: 201-086 Hik orp Alaska,LLI API: 50-029-23017-00 Well Name: NS-13 API Number: 50-029-23017-00 Current Status: Injecting Rig: EL&SL Estimated Start Date: July 20, 2017 Estimated Duration: 4 day Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 201-086 First Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE Number: Well EZ Required Yes Current Bottom Hole Pressure: 5,124 psi @ 11,100'TVDSS (Based on SBHPS on NS-13 6/28/16) Maximum Expected BHP: 5,124 psi @ 11,100'TVDSS (Based on SBHPS on NS-13 6/28/16) Max. Proposed Surface Pressure: 4014psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 3814psi (Taken on 3/13/17) Min ID: 2.205" @ 11,864' 2-7/8"XN Nip In Swell Packer Patch Reference Log: SLB Packer Setting Record 5/27/13 Brief Well Summary: The well was recently converted from a producer to a gas injector. Gas injection began 5/13/17 at 22 mmscfd at max pressure of 4,675psi.This is less than half of the injection rate of the other Northstar Injectors and the well is believe to be limited at the perforations. In June 2013 2-7/8"swell packer patch was set across the upper—150' of perforations for gas shutoff leaving only a 20' interval from 11,874'-11,894' open. The patch has 30' sections of swell packer rubber separated by 3' snap latches and will require multiple perforations to regain injectivity across the patched interval. Objective: Use Eline to perforate 11,755'-11,855' across the swell packer patch to increase injectivity. Proposed gun runs must be confirmed with respect to signed Final Approved Perforation Request Form provided by Reservoir Engineer: Procedure: Non Sundried Operations Slickline 1. RU SL unit and pressure test to 250psi low/4,050psi high. 2. RIH and pull 4-1/2" MCX SSSV from 1,997' md. 3. Drift tubing with 20 ft 2" dummy gun to TD 4. RD SL. Sundry Procedure(Approval Required to Proceed): Eline 1. RU EL unit and pressure test to 250psi low 4,000psi high. 2. MU perforating tool string with 2", 6spf, 60 deg phasing HSD guns. • RePerf Well: NS-13 PTD: 201-086 Iiilcorp Alaska,LU API: 50-029-23017-00 3. RIH and correlate 1'gun run to reference log SLB Packer Setting Record 5/27/13. Contact OE Wyatt Rivard at 1(509) 670-8001 or OE Taylor Wellman at 1(907) 947-9533 prior to perforating for final approval of tie in. 4. Perforate 1st gun run as per Table 1: NS-13 Proposed Re-Perf Gun Runs. POOH. a. Note any tubing pressure change in WSR. 5. Repeat steps 2-4 for gun runs 2-5 as per Table 1: NS-13 Proposed Re-Perf Gun Runs. 6. RD Eline. Gun Run# Perf Top Perf Bottom Perf Length 1 ±11,835' ±11,855' 20 2 ±11,815' ±11,835' 20 3 ±11,795' ±11,815' 20 4 ±11,775' ±11,795' 20 5 ±11,755' ±11,775' 20 Total 100 Table 1: NS-13 Proposed Re-Perf Gun Runs Slickline 1. RU SL unit and pressure test to 250psi low/4050 psi high. 2. RIH and set 4-1/2" MCX SSSV from 1,997' md. a. Bleed down tubing pressure to "Opsi and monitor to confirm good set. 3. RD SL. Attachments: Proposed Schematic/Well Schematic • 0 Northstar Unit Well: NS-13 SCHEMATIC Last Completed: 12/02/2001 LIilcorp Alaska,LLC PTD: 201-086 TREE&WELLHEAD Orig.KBE=56.19'/BFE=40.29'(CB 15.9') Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13 5/8"Multibowl SKSI 20" OPEN HOLE/CEMENT DETAIL i I 20" Driven .. ' 1 193=53188.: 140 sx"L",470 sx Class"G",1,853 sx PF"E",in 16"Hole [ L 68 sx Lite,400 sx Class"G",503 sx Econolite in 12-1/4"Hole 13-3/8" 7" 318 sx Class"G"in 8-1/2"Hole 4-1/2" 97 sx Class"G"in 6-1/8"Hole CASING DETAIL 2 1 , Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 169/X-56/N/A N/A Surface 201' N/A 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,198' 0.1497 9-5/8" Intermediate 47/L-80/Btrc. 8.681 Surface 10,083' 0.0732 7" Liner 26/L-80/BTC-M 6.276 9,900' 11,488' 0.0383 ' 1 4-1/2" Liner 12.6/13Cr/Vam Ace 3.958 11,276' 11,975' 0.0152 '' TUBING DETAIL 4-1/2" Tubing 12.6/13Cr/Vam Ace 3.958 Surface 11,270' 0.0152 WELL INCLINATION DETAIL KOP @ 2,363' Max Hole Angle=31 deg.@ 6,354' Max Angle at Top Perf:4 Deg.@ 11,724' ' JEWELRY DETAIL No Depth Item 1 1,997' 4-1/2"MCX Injection Valve w/HXO SVL Nipple- ID=3.813" 2 5,161' CAMCO GLM w/RK latch ST1:Port=0,Dev=30,VIv=Dummy,TVD=4,910'-Set 11/28/2001 3 9,900' 9-5/8"x 7"Liner Top Packer and Hanger • 4 11,178' 4-1/2"Cidra PT Gauge,ID=3.813" IL. 3 5 11,200' 4-1/2"HES X Nipple,ID=3.813" j ,,_ 6 11,222' 7"x 4-1/2"Baker S-3 Perm Packer,ID=3.875" 7 11,246' 4-1/2"HES X Nipple,ID=3.813" 8 11,257' 4-1/2"HES XN Nipple,ID=3.800",milled 4/2/2013 9-5/8"• • 9 11,276' 7"x 5"Baker Liner Top Packer 1 4 10 11,269' 4-1/2"WLEG,ID=3.958"-Bottom @ 11,270' IF 11 11,290' 7"x 5"Baker Liner Hanger 5 12 11,299' 5"x 4-1/2"X0,ID=3.958" li It 0 $.17.1 6 13 11,657' 45 KB Packer w/2-7/8"QCLL Stinger,I1)=2.441"(4/17/2014) . ! 14 11,663' 4-1/2"x 2-7/8"QCLL Swell Packer Patch,(6/03/2013)Bottom @ 11,866' II 11 8 7 15 11,864' 2-7/8"HES XN Nipple,ID=2.205" PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status II ? =J� 9 11,724' 11,864' 10,980 11,120 140 12/01/2001 Closed&Sgzd 19 11,856' 11,874' 11,112 11,130 18 4/16/2007 Closed 11 Ivishak 11,860' 11,886' 11,116 11,142 26 1/19/2005 Closed&Sqzd 12 11,874' 11,894' 11,130 11,150 20 4/08/2007 Open .1 11,880' 11,890' 11,136 11,146 10 4/01/2007 Open • 13 GENERAL WELL INFO Mn 0=2.205"@ ;r 14 API:50-029-23017-00-00 11,864',2-7/8 XN € Completed-12/2/2001 Jf• ;o_4, 5 Ivishak SAFETY NOTE N Well requires a SSSV. 4-1/2"Chrome Tubing&Liner TD©11,891'Tagged 3/23/2014 .y t 4.1/2" .• ;+•; TD=12,000'(MD)/TD=11,256'(TVD) PBTD=11,910'(MD)/PBTD=11,166'(TVD) Revised By:TDF 5/16/2017 0 0 Northstar Unit ticWell: NS-13 PROPOSED Last Completed: 12/02/2001 PTD: 201-086 IIilcorp Alaska,LLC Orig.KBE=56.19BFE=40.29'(CB 15.9') TREE&WELLHEAD '! Tree ABB-VGI 5-1/8"5KSI [ LWellhead ABB-VGI 13-5/8"Multibowl 5KSI 20' OPEN HOLE/CEMENT DETAIL 20" Driven ( 1 { 1 13-3/8" 140 sx"L",470 sx Class"G",1,853 sx PF"E",in 16"Hole 9-5/8" 68 sx Lite,400 sx Class"G",503 sx Econolite in 12-1/4"Hole 13-3/8" 7" 318 sx Class"G"in 8-1/r Hole 4-1/2" 97 sx Class"G"in 6-1/8"Hole CASING DETAIL 2 Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 169/X-56/N/A N/A Surface 201' N/A 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,198' 0.1497 9-5/8" Intermediate 47/L-80/Btrc. 8.681 Surface 10,083' 0.0732 7" Liner 26/L-80/BTC-M 6.276 9,900' 11,488' 0.0383 4-1/2" Liner 12.6/13Cr/Vam Ace 3.958 11,276' 11,975' 0.0152 1. TUBING DETAIL 1` 4-1/2" Tubing 12.6/13Cr/Vam Ace 3.958 Surface 11,270' 0.0152 WELL INCLINATION DETAIL KOP @ 2,363' Max Hole Angle=31 deg.@ 6,354' Max Angle at Top Perf:4 Deg.@ 11,724' : JEWELRY DETAIL I No Depth Item 1 1,997' 4-1/2"MCX Injection Valve w/HXO SVL Nipple- ID=3.813" 2 5461' CAMCO GLM w/RK latch ST1:Port=0,Dev=30,VIv=Dummy,TVD=4,910'-Set 11/28/2001 3 9,900' 9-5/8"x 7"Liner Top Packer and Hanger I 4 11,178' 4-1/2"Cidra PT Gauge,ID=3.813" IL 3 5 11,200' 4-1/2"HES X Nipple,ID=3.813" j6 11,222' 7"x 4-1/2"Baker S-3 Perm Packer,ID=3.875" ( 7 11,246' 4-1/r HES X Nipple,ID=3.813" 1 8 11,257' 4-1/2"HES XN Nipple,ID=3.800",milled 4/2/2013 9-5/8" ! • 9 11,276' 7"x 5"Baker Liner Top Packer alt 4 10 11,269' 4-1/2"WLEG,ID=3.958"-Bottom @ 11,270' 1M 11 11,290' 7"x 5"Baker Liner Hanger 5011 107: 12 11,299' S"x 4-1/2"XO,ID=3.958" 6 13 11,657' 45 KB Packer w/2-7/8"QCLL Stinger,I0=2.441"(4/17/2014) 14 11,663' 4-1/2"x 2-7/8"QCLL Swell Packer Patch,(6/03/2013)Bottom @ 11,866' 15 11,864' 2-7/8"HES XN Nipple,ID=2.205" i 11 PERFORATION DETAIL a 8 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status L' -11 9 11,724' 11,864' 10,980 11,120 140 12/01/2001 Closed&Sqzd ±11,755' ±11,855' ±11,011' ±11,111 ±100 Future Pending V J11.7 11,856' 11,874' 11,112 11,130 18 4/16/2007 Closed 12 Ivishak 11,860' 11,886' 11,116 11,142 26 1/19/2005 Closed&Sqzd 11,874' 11,894' 11,130 11,150 20 4/08/2007 Open ,m 1 11,880' 11,890' 11,136 11,146 10 4/01/2007 Open 7" `I'13 rMinlD=2.205"@ J14 GENERAL WELL INFO 11,864',2-7/8"XN * API:50-029-23017-00-00 Completed-12/2/2001 x'15 o-Ivishak ,-1,-.,. SAFETY NOTE TD@11,891'Tagged :„ ' Well requires a SSSV. 4-1/2"Chrome Tubing&Liner 3/23/2014 ai 4-1/2,' TD=12,000'(MD)/TD=11,256'(TVD) PBTD=11,910'(MD)/PBTD=11,166'(TVD) Revised By:TDF 6/27/2017 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,May 22,2017 P.I.Supervisor Relet 51�l ZZJ17 SUBJECT: Mechanical Integrity Tests Rel HILCORP ALASKA LLC NS-13 FROM: Matt Herrera NORTHSTAR UNIT NS-13 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,"- _ NON-CONFIDENTIAL Comm Well Name NORTHSTAR UNIT NS-13 API Well Number 50-029-23017-00-00 Inspector Name: Matt Herrera Permit Number: 201-086-0 Inspection Date: 5/18/2017 Insp Num: mitMFH170518155140 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well] NS-13 - 1Type Inj G TVD 10533 ' Tubing 4687 . 4684 - 4686 4682 PTD 2010860 Type Testl SPT Test psi 2633 IA 755 2720 - 2707 - 2706 - BBL Pumped: 10.2 ' iBBL Returned: 12 OA 207 351 - 348 - 351 - Interval INITAL P/F P V Notes: Initial MIT post conversion to Gas Injector 2700 PSI IA test Pressure Per Operator CO Cu,-rn.j- LJ-e t( sc4np,,,tc,A,c A4-4{Actteeil .! , el) .ju1'- �d1 `? 7 ' s , Monday,May 22,2017 Page 1 of 1 • • Unit SCHEMA Ar- -c- .3 ►leted: 12/02/2001 Mean)Alaska,t r c 086 de-Kere ._ Orig.KBE=56.19'/BFE=40.29'(CB 15.9') Tree Wellhe 20" ( , O J i 1 1 (l 20" Driven -h" 13-3/8" 140 sx"L",470 sx Class"G",1,853 sx PF"E",in 16"Hole r 9-5/8" 68 sx Lite,400 sx Class"G",503 sx Econolite in 12-1/4"Hole 13-3/8" 7" 318 sx Class"G"in 8-1/2"Hole 4-1/2" 97 sx Class"G"in 6-1/8"Hole 2 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 169/X-56/N/A N/A Surface 201' N/A 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,198' 0.1497 9-5/8" Intermediate 47/L-80/Btrc. 8.681 Surface 10,083' 0.0732 7" Liner 26/L-80/BTC-M 6.276 9,900' 11,488' 0.0383 4-1/2" Liner 12.6/13Cr/Vam Ace 3.958 11,276' 11,975' 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr/Vam Ace 3.958 Surface 11,270' 0.0152 WELL INCLINATION DETAIL KOP @ 2,363' Max Hole Angle=31 deg.@ 6,354' • Max Angle at Top Perf:4 Deg.@ 11,724' JEWELRY DETAIL No Depth Item 1 1,997' 4-1/2"MCX Injection Valve w/HXO SVL Nipple- ID=3.813" 2 5,161' CAMCO GLM w/RK latch ST1:Port=0,Dev=30,VIv=Dummy,TVD=4,910'-Set 11/28/2001 3 9,900' 9-5/8"x 7"Liner Top Packer and Hanger 4 11,178' 4-1/2"Cidra PT Gauge,ID=3.813" s- 'r 3 5 11,200' 4-1/2"HES X Nipple,ID=3.813" j 6 11,222' 7"x 4-1/2"Baker S-3 Perm Packer,ID=3.875" �� 7 11,246' 4-1/2"HES X Nipple,ID=3.813" 8 11,257' 4-1/2"HES XN Nipple,ID=3.800",milled 4/2/2013 9-5/8"A 1 9 11,276' 7"x 5"Baker Liner Top Packer TV 7-7 105-31..f+ Mt 4 10 11,269' 4-1/2"WLEG,ID=3.958"-Bottom @ 11,270' 11 11,290' 7"x 5"Baker Liner Hanger fu(--t12 12 11,299' 5"x 4-1/2"XO,ID=3.958" ✓ ;' 6 13 11,657' 45 KB Packer w/2-7/8"QCLL Stinger,ID=2.441"(4/17/2014) iii ': 14 11,663' 4-1/2"x 2-7/8"QCLL Swell Packer Patch,(6/03/2013)Bottom @ 11,866' 7 15 11,864' 2-7/8"HES XN Nipple,ID=2.205" ` PERFORATION DETAIL 4--ri 8 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status IL ''JI 9 11,724' 11,864' 10,980 11,120 140 12/01/2001 Closed&Sqzd .- 110 11,856' 11,874' 11,112 11,130 18 4/16/2007 Closed 11 Ivishak 11,860' 11,886' 11,116 11,142 26 1/19/2005 Closed&Sqzd 12 11,874' 11,894' 11,130 11,150 20 4/08/2007 Open ';- } 11,880' 11,890' 11,136 11,146 10 4/01/2007 Open 1. x`13 GENERAL WELL INFO Min ID 2.205"@ [ 14 API:50-029-23017-00-00 11,864',2-7/8"XN 4 _ �� Completed-12/2/2001 � Iishak ' -'x15 SAFETY NOTE TD@11,891'Tagged Well requires a SSSV. 4-1/2"Chrome Tubing&Liner 3/23/2014 lw ¢ur,' gip. TD=12,000'(MD)/TD=11,256'(TVD) PBTD=11,910'(MD)/PBTD=11,166'(TVD) Revised By:TDF 5/16/2017 iiiiikqi,_ ios_13. III ri-b zoi08(0 NS-13 Directional Survey *WELL 500292301700 *XYUNITS F *DEPUNITS F *COLUMNS *MD *TVD *EW *NS 0.00 0.00 0.00 0.00 41.04 41.04 0.00 0.00 50.42 50.42 0.03 -0.02 100.42 100.42 0.35 -0.37 150.42 150.41 0.83 -1.04 180.42 180.40 1.21 -1.58 270.42 270.39 1.98 -2.66 365.32 365.29 2.31 -2.91 456.42 456.39 2.56 -2.80 547.42 547.39 2.68 -2.67 638.42 638.39 2.70 -2.59 729.42 729.39 2.73 -2.55 820.52 820.49 2.72 -2.49 911.52 911.49 2.66 -2.42 1006.72 1006.69 2.55 -2.37 1027.52 1027.49 2.51 -2.32 1124.75 1124.72 2.30 -1.75 1218.46 1218.43 2.32 -0.96 1316.02 1315.98 2.46 -0.22 1411.10 1411.06 2.69 0.46 1506.56 1506.52 2.89 1.10 1601.85 1601.81 2.86 1.62 1696.43 1696.38 2.82 2.25 1791.50 1791.45 2.73 3.09 1885.78 1885.73 2.55 3.94 1982.05 1981.99 2.43 4.70 2075.91 2075.85 2.51 5.44 2171.96 2171.90 2.83 6.04 2267.80 2267.74 3.11 6.43 2362.90 2362.82 1.92 6.91 2458.09 2457.93 -1.99 7.74 2553.84 2553.39 -9.02 9.69 2649.80 2648.68 -19.82 12.86 2744.21 2741.87 -34.50 16.34 2838.85 2834.51 -53.40 20.36 2933.95 2926.71 -76.15 25.26 3029.62 3018.53 -102.31 31.24 3124.94 3109.07 -131.47 37.44 3141.73 3124.92 -136.90 38.51 3218.16 3196.94 -161.96 43.64 3313.04 3285.81 -194.52 50.33 3408.41 3374.38 -229.27 56.83 3503.50 3461.76 -266.26 63.02 3598.71 3547.34 -307.33 70.14 Page 1 S ! kb TilD NS-13 Directional Survey 3693.83 3631.28 -351.31 78.36 3789.74 3715.51 -396.14 88.04 3883.58 3797.17 -441.15 98.61 3979.40 3879.88 -488.18 109.92 4075.35 3962.82 -535.07 121.31 4169.68 4044.74 -580.76 131.29 4264.76 4127.64 -626.48 140.08 4360.21 4211.06 -672.00 148.92 4454.99 4293.64 -717.69 157.66 4550.17 4376.38 -763.76 167.15 4645.02 4459.22 -808.80 177.49 4740.12 4542.40 -853.61 188.21 4836.66 4626.69 -899.01 200.63 4931.66 4709.84 -943.16 213.36 5026.46 4792.90 -986.94 226.42 5121.79 4876.05 -1031.52 240.09 5216.06 4957.78 -1076.48 253.72 5311.34 5039.91 -1122.61 268.03 5406.83 5122.33 -1168.69 282.22 5501.26 5204.24 -1213.87 295.15 5597.29 5287.90 -1259.28 307.81 5692.77 5371.50 -1303.66 320.36 5788.22 5454.93 -1348.14 333.49 5882.64 5537.02 -1392.43 348.15 5978.19 5620.31 -1436.82 362.99 6073.78 5703.59 -1481.65 376.88 6167.71 5785.02 -1526.43 390.52 6262.67 5867.08 -1572.29 403.95 6354.23 5945.89 -1617.33 415.98 6382.86 5970.52 -1631.45 419.62 6479.04 6053.58 -1678.41 431.72 6572.72 6134.87 -1723.52 443.29 6666.00 6216.19 -1767.75 454.73 6761.07 6299.13 -1812.80 466.12 6858.55 6383.94 -1859.51 477.38 6952.49 6465.55 -1904.77 488.21 7048.51 6548.98 -1951.12 498.78 7142.56 6630.89 -1996.33 508.33 7238.62 6714.91 -2041.89 517.94 7333.53 6798.09 -2086.64 527.21 7428.93 6881.69 -2131.72 536.20 7522.83 6963.94 -2176.11 545.19 7617.45 7046.79 -2220.89 554.41 7712.87 7130.59 -2265.62 563.35 7808.90 7215.22 -2310.16 572.15 7904.60 7299.62 -2354.37 581.13 8000.31 7384.30 -2398.04 590.18 8095.56 7469.08 -2440.54 598.96 Page 2 • 411 411 • .L0 TL' ' NS-13 Directional Survey 8190.72 7554.29 -2482.02 607.59 8285.60 7639.81 -2522.21 616.14 8381.32 7726.66 -2561.54 624.69 8476.90 7813.98 -2599.49 633.04 8573.45 7902.81 -2636.42 641.27 8668.68 7990.79 -2671.93 649.44 8763.27 8078.42 -2706.63 657.43 8858.37 8166.95 -2740.44 665.38 8953.94 8256.38 -2773.17 673.47 9049.04 8345.60 -2805.12 681.43 9144.69 8435.51 -2836.69 689.71 9239.37 8524.68 -2867.33 698.25 9335.01 8615.15 -2897.31 706.21 9430.26 8706.14 -2924.66 712.84 9525.44 8797.93 -2949.18 718.47 9620.58 8890.29 -2971.50 723.21 9715.10 8982.58 -2991.53 727.25 9810.97 9076.61 -3009.79 731.02 9905.24 9169.42 -3026.01 734.44 9999.90 9262.98 -3039.96 737.61 10016.77 9279.70 -3042.16 738.15 10150.48 9412.26 -3059.05 742.73 10244.93 9506.02 -3070.00 745.83 10339.76 9600.29 -3080.01 748.16 10434.55 9694.59 -3089.35 750.50 10530.20 9789.78 -3098.26 753.29 10624.93 9884.10 -3106.70 755.99 10719.93 9978.72 -3114.79 758.41 (� 10814.37 10072.83 -3122.37 760.87 Pcc( - rLfl 10909.06 10167.22 -3129.35 763.69 11005.44 10263.33 -3135.73 767.02 Ltd 11101.13 10358.75 -3141.38 771.28 11195.17 10452.54 -3146.28 776.07 tins- 104-5 42/611289.54 10546.69 -3150.61 780.97 /ltifr X 11385.30 10642.23 -3154.42 786.07 iizel 10547 11420.14 10677.00 -3155.69 787.91 11515.93 10772.61 -3159.03 792.78C4 11603.90 10860.43 -3161.78 797.13 ( _4 ) c, X= �a4ss r � ' 11708.34 10964.69 -3164.61 802.48 11802.31 11058.49 -3167.03 807.72 c k = l®c534 - 1 11897.37 11153.36 -3169.51 813.20 l.. 11920.78 11176.72 -3170.23 814.48 12000.00 11255.78 -3173.06 818.55 l. Z1 eA "1 Page 3 STATE OF ALASKA ALADA OIL AND GAS CONSERVATION COIVIISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Plug Perforations U Fracture Stimulate LJ Pull Tubing U Operations shutdown LI Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Convert to Injector • Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑., Exploratory ❑ 201-086 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number AK 99503 50-029-23017-00-00 7.Property Designation(Lease Number): 8.Well Name and Number ADL0312799 NORTHSTAR UNIT NS-13 RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A NORTHSTAR/NORTHSTAR OIL 11.Present Well Condition Summary: q1,u. i U 2017 Total Depth measured 12,000 feet Plugs measured N/A feAO G • true vertical 11,256 feet Junk measured N/A feet 9,900, 11,222& Effective Depth measured 11,915 feet Packer measured 11276 feet 9,164, 10,479& true vertical 11,171 feet true vertical 10,533 feet Casing Length Size MD TVD Burst Collapse Conductor 161' 20" 161' 161' N/A N/A Surface 3,198' 13-3/8" 3,198' 3,178' 5,020psi 2,260psi Intermediate 10,083' 9-5/8" 10,083' 9,345' 6,870psi 4,760psi Liner 1,588' 7" 11,488' 10,745' 7,240psi 5,410psi Liner 699' 4-1/2" 11,975' 11,231' 8,430psi 7,500psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet £''✓,t1 C f''i Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13Cr/VAM-ACE 11,270' 10,527' 9-5/8"x 7"LT 7"x 4-1/2"Perm Packers and SSSV(type,measured and true vertical depth) 7"x 5"LTP See Above 4-1/2"HES SSSV 1,997 MD/1,997 TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 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 88 0 Subsequent to operation: 0 22,308 0 179 4,678 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory El Development❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ Q SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-590 R W r� A Authorized Name: Bo York ' Contact Name: S,.0,-Taylor Wellman Authorized Title: Operations Manager Contact Email: twellman(p�hilcorp.corn ,.�,+ iS114113 . Authorized Signature: I/ /ed.,. Dab 5/X/2017 Contact Phone: 777-8449 Form 10 101 Rcviccd —017 Submit Original Only /.1h 74 5--Ze-17 RBDMS v/r^"" 1 9 2017 . • Noe :rthstar Unit HWllNS-13 SCHEMATIC Last Completed: 12/02/2001 Maori)Alaska,LLC PTD: 201-086 Orig.KBE=56.19'!BFE=40.29'(CB 15.9') TREE&WELLHEAD Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl SKS! 20" OPEN HOLE/CEMENT DETAIL 20" Driven 13-3/8" 140 sx"L",470 sx Class"G",1,853 sx PF"E",in 16"Hole 9-5/8" 68 sx Lite,400 sx Class"G",503 sx Econolite in 12-1/4"Hole 13-3/8 7" 318 sx Class"G"in 8-1/2"Hole 4-1/2" 97 sx Class"G"in 6-1/8"Hole 2 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 169/X-56/N/A N/A Surface 201' N/A 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,198' 0.1497 9-5/8" Intermediate 47/L-80/Btrc. 8.681 Surface 10,083' 0.0732 7" Liner 26/L-80/BTC-M 6.276 9,900' 11,488' 0.0383 4-1/2" Liner 12.6/13Cr/Vam Ace 3.958 11,276' 11,975' 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr/Vam Ace 3.958 Surface 11,270' 0.0152 • WELL INCLINATION DETAIL KOP @ 2,363' Max Hole Angle=31 deg.@ 6,354' Max Angle at Top Perf:4 Deg.@ 11,724' JEWELRY DETAIL No Depth Item 1 1,997' 4-1/2"MCX Injection Valve w/HXO SVL Nipple- ID=3.813" 2 5,161' CAMCO GLM w/RK latch ST1:Port=0,Dev=30,Vlv=Dummy,TVD=4,910'-Set 11/28/2001 3 9,900' 9-5/8"x 7"Liner Top Packer and Hanger 4 11,178' 4-1/2"Cidra PT Gauge,ID=3.813" IL 3 5 11,200' 4-1/2"HES X Nipple,ID=3.813" I 6 11,222' 7"x 4-1/2"Baker S-3 Perm Packer,10=3.875" 'j 7 11,246' 4-1/2"HES X Nipple,ID=3.813" ~ 8 11,257' 4-1/2"HES XN Nipple,ID=3.800",milled 4/2/2013 9-5/8" • 9 11,276' 7"x 5"Baker Liner Top Packer 4 10 11,269' 4-1/2"WLEG,ID=3.958"-Bottom @ 11,270' 11 12 11,290' 7"x 5"Baker Liner Hanger It i5 11,299' 5"x 4-1/2"X0,ID=3.958" lk 01 6 13 11,657' 45 KB Packer w/2-7/8"QCLL Stinger,I0=2.441"(4/17/2014) I di 14 11,663' 4-1/2"x 2-7/8"QCLL Swell Packer Patch,(6/03/2013)Bottom @ 11,866' 7 15 11,864' 2-7/8"HES XN Nipple,10=2.205" PERFORATION DETAIL 8 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 1L J1 9 11,724' 11,864' 10,980 11,120 140 12/01/2001 Closed&Sqzd J 10 11,856' 11,874' 11,112 11,130 11,142 18 4/16/2007 Closed 11 Ivishak 11,860' 11,886' 11,116 26 1/19/2005 Closed&Sgzd k 12 11,874' 11,894' 11,130 11,150 20 4/08/2007 Open a" , 11,880' 11,890' 11,136 11,146 10 4/01/2007 Open Min IC 2.205" r 13 GENERAL WELL INFO 11,864',2-7/8 N 14 API:50-029-23017-00-00 Completed-12 2/2001 .:= p / .u-115 Ivishak SAFETY NOTE to Well requires a SSSV. 4-1/2"Chrome Tubing&Liner TD©11,891 Tagged ,, 3/23,2014 4 a 4-1/2"'' . TD=12,000'(MD)/TD=11,256'(1VD) PBTD=11,910'(MD)/PBTD=11,166'(TVD) Revised By:TDF 5/16/2017 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date _ End Date NS-13 Slickline 50-029-23017-00-00 201-086 3/17/17 4/17/17 Daily Operations: 3/15/2017 -Wednesday No activity to report. 3/16/2017 -Thursday No activity to report. 3/17/2017 - Friday Rig up lubricator to set 5" 2 way check. Close swab and test to 4K-PASS. Set 2 Way check and tewst 2 Way to 4000.-PASS safe out tree.Pull wellhouse and flowlines and platforms. Leave wing support base on adapter ND 5 1/8" 5K tree down to master valve. SSV and Swab/otis will be kept on new configuration. Install new 5 1/8:1_65_01_, master valve in same configuration as when we pullled old pone.;Build new tree from SSV on up in shop oin Injection configuration. Using New: Cross, 3-1/8" wing, 5-1/8" lnj flange, 5-1/8" wing, 5-1/8" ell, 5-1/8" 6,500 flg x grayloc choke. 3/18/2017 -Saturday Install new 5 1/8" 6500 tree on master. ND adapter and tree and orientate to Injector position. (straight at door). MU adapter/Tree.Test Tree to 250 low for 5 min and to 6,500 high with diesel for 5 min. PASS Leave 1,500 on tbg and test Tbg Hgr void to 6,500 for 5 Min. No observation ports noted on this adapter. Pass. Rig up lubricator to pull 2 way. Tested Lubricator against swab to 4,000- PASS. RIH and pull 2 way check. 3/19/2017-Sunday No activity to report. 3/20/2017- Monday No activity to report. 3/21/2017-Tuesday No activity to report. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-13 Slickline 50-029-23017-00-00 201-086 3/17/17 4/17/17 Daily Operations: 4/12/2017-Wednesday No activity to report. 4/13/2017 -Thursday No activity to report. 4/14/2017 - Friday ***WELL SHUT-IN ON ARRIVAL*** (sbhps,c/o sssv). PT PCE 250#-LOW/4,600#-HIGH. RAN DUAL SPARTEK SBHPS GUAGES AS PER PROGRAM USING +36' CORR. W/4 STOPS (good data). DRIFT TBG W/3.85" G. RING TO QOS SSSV AT 1,960' SLM (1,997' MD). WINDS GUSTING TO 39 MPH, LAID DOWN FOR DAY 4/15/2017 -Saturday No activity to report. 4/16/2017 -Sunday PT PCE 250#-LOW/4,600#-HIGH. ATTEMPTED TO PULL 4-1/2" QOS SSSV FROM 1,997' MD (pulled fishing neck &expander madrel from x-lock). STANDBY DUE TO HIGH WIND. 4/17/2017 - Monday PT PCE 250#-LOW/4,600#-HIGH. PULLED REMAINING X-LOCK &4-1/2" QOS SSSV. SET 4-1/2" MCX ON CARRIER (ser#HM- 12) (2 REG PKG STACKS W/ORINGS) (NO EQ DEV) (1.56" BEAN) IN HXO SVLN AT 1,997' MD. PERFORMED SUCCESSFUL DRAW DOWN TEST ON MCX 4/18/2017 -Tuesday No activity to report. • • • ''of 7r4 s THE STATE Alaska Oil and Gas �,�• o f�L /� C J<T n Conservation Commission nJ � Sy2 i� 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Tti Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Mike Dunn Operations Manager WO FEB 2 c 2017 Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Northstar Field,Northstar Oil Pool,NU NS-13 Permit to Drill Number: 201-086 Sundry Number: 316-590 Dear Mr. Dunn: 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, /a94e4-474^--- Cathy P. Foerster Chair r� DATED this day of November, 2016. RBDIVIS (,L-NOV 2 8 2818 III RECEIVED . STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 16 2016 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGGC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other: Convert to Injector 0• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory 0 Development Q 201-086 3.Address: 3800 Centerpoint Dr,Suite 1400Stratigraphic El Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23017-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 458A Will planned perforations require a spacing exception? Yes 0 No 0 NORTHSTAR UNIT NS-13 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: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,000' 11,256' 11,915' 11,171' 3,850 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 161' 20" 161' 161' N/A N/A Surface 3,198' 13-3/8" 3,198' 3,178' 5,020psi 2,260psi Intermediate 10,083' 9-5/8" 10,083' 9,345' 6,870psi 4,760psi Liner 1,588' 7" 11,488' 10,745' 7,240psi 5,410psi Liner 699' 4-1/2" 11,975' 11,231' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/13Cr/VAM-ACE 11,270 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"x 7"LTP,7"x 4-1/2"Perm,7"x 5"LTP and 4-1/2"HES SSSV 9,900 MD/9,164 TVD,11,222 MD/10,479 TVD,11,276 MD/10,533 TVD and 1,997 MD/ 1,997 TVD 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory 0 Stratigraphic❑ Development❑ Service 0 14.Estimated Date for 15.Well Status after proposed work: 12/1/2016 Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ Q Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Wellman 7 ,/ Email twellman@hilcorp.com Printed Name , - Dunn Title Operations Manager r. Signature / Phone 777-8382 Date 11/14/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `CA _ .6- C) Mir- IA Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance� ❑ AOther: JF- ./1 34CC •'k wi +ate -- /V1. t'7-/A `;, 31 5 ,C+e✓� 'vrturic r 1G. A t - r,,,,,-1,.' _ f 2 C:..k-e✓' Pj&C.�,,, ,,..— - c?._p ,,^Li..42 2-c.., ,gar--C.. Z .itr 2 C)"') Post Initial Injection MIT Req'd? Yes ❑ No 0 . jc_- w 11.-L I t to Spacing Exception Required? Yes ❑ No 3/ Subsequent Form Required: 1 ca --`/C3 /y RBDIVIS L,'"NOV 2 8 2010 I p APPROVED BY Approved by: , q -r (z.. __ COMMISSIONER THE COMMISSION Date: !/_2.2.,...--4, - * ® RIG * ' A Submitsn Form and Form 1 1�4o i e 1{i2o15 a valid for 12 months from the date of approval. Attachments in Duplicate • • Convert to GI Well: NS-13 PTD: 201-086 Mom)Alaska,LI) API: 50-029-23017-00-00 Well Name: NS-13 API Number: 50-029-23017-00-00 Current Status: SI (Operable Cycle Well) Rig: SL Estimated Start Date: December 1, 2016 Estimated Duration: 2 Reg.Approval Req'std? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 201-086 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8847 (0) (509) 670-8001 (M) AFE: WeIIEZ Entry Required: Yes Current Bottom Hole Pressure: 5,113psi @ 11,100' TVD (Based on SBHPS on 06/28/16) Current Bottom Hole Pressure: 5,113psi @ 11,100' TVD (Based on SBHPS on 06/28/16) Max. Proposed Surface Pressure: 3850psi (SITP on 08/05/16) Brief Well Summary: The Northstar well NS-13 is a cycle well with low on-production time. The well is located near the top of structure for the Ivishak and is ideally placed for a crestal gas injector. As a production well the well last produced 140bo, 23mmscf,42bw, TFP=2426psi and a GOR=163.6k. The additional gas injection capacity will allow for additional gas handling capacity in the compressors. / 0460/., /1%7/4 1%7//�d Objective: 1. Convert the well service to gas injection / 4- Variance Requested: 20AAC25.412(b) Packer will be set greater than 200ft measured depth from open perfs P.le: rks• Area of Review—Northstar NS-13 (201-086) Prior to the conversion of well NS-13 from producer to gas injector, an Area of Review (AOR) must be - conducted. This AOR found one other well (NS-14A) within 1/4 mile of NS-13's entry point into the Ivishak Formation. Table 2: Wells within AOR Well Name PTD Distance, Ft. Annulus Integrity NS-13 , 201-086 0' MIT-IA on 11/29/01 passed to 4200psi MIT-IA on 4/21/05 passed to 2000psi NS-14A , 205-202 860' MIT-IA on 12/11/05 passed to 4200 psi MIT-T on 12/11/05 passed to 5000 psi Table 3: Completion Detail API Well No Permit Well Current Status Zonal isolation (method) No bond log run across 7" liner. Estimated TOC (calculated) at 9900' 50-029-23017-00-00 201-086 NS 13 S/I Producer— md. Bumped plug, held 3500psi, bled & Northstar Oil Pool floats held. No losses noted in daily drilling report. 1751' above Ivishak sand. • Convert to GI Well: NS-13 PTD:201-086 Hi, ,AbiEka..LLi API:50-029-23017-00-00 USIT log run across 4-1/2" liner on 50-029-23017-00-00 201-086 NS-13 S/I Producer— 11/29/01 indicates a TOC at 11,276' and Northstar Oil Pool (top of 4-1/2" liner). —375' above the Ivishak sand. No bond log run across 7" liner. Estimated TOC (calculated) at 10,039' S/I Producer— md. Bumped plug at calculated 50-029-23026-00-00 205-202 NS-14A Northstar Oil Pool displacement, held 4200psi, bled & floats held. No losses noted in daily drilling report. 2518' above Ivishak sand. No bond log run across 4-1/2" liner. Estimated TOC (calculated) at 12,263' S/I Producer— md. Bumped plug at calculated 50-029-23026-00-00 205-202 NS-14A Northstar Oil Pool displacement, held 2435psi, bled & floats held. No losses noted in daily drilling report. -294' above Ivishak sand. • rte" Procedure: Non-sundried operations / L Operations 1. Conduct an MIT-IA to 2700psi. 6 �— a. 0.25 x TVD of packer (0.25 x 10,484' and = 2621psi). h1�1'/' Procedure: Sundried operations Slickline 2. RU SL unit and pressure test to 250psi low/4,000psi high. a� 3. Pull 4-1/2" QOS SSSV from 1997' md. P ssv 4. Set 4-1/2" Al Injection SSSV at 1997' md. S a. Bleed down tubing pressure to "'Opsi and monitor to confirm good set. 5. RD SL. Tree and Wellhead 6. Close the master and swab valve. RU BPV lubricator and pressure test to 4000psi. Open swab and master valves. 7. Set TWC in hanger profile and pressure test to 4000psi. RD lubricator. 8. Bleed down all pressures and unbolt and replace the flow cross and the companion side 3-1/8" valve. b. Both .the flow cross and the 3-1/8" companion valve are to be uprated to 6500psi components. All other portions of the tree are already rated to 6500psi. 9. Pressure test the tree to 250psi low for 5 minutes (stabilized) and 6500p.si for 5 minutes (stabilized). a. Stab into and monitor the tubing hanger test void to ensure the neck seals are intact while conducting the pressure test of the tree. 10. Bleed the pressure in the tree to 1500psi. Pressure test the Tubing Hanger Void to 6500psi. • • Convert to GI Well: NS-13 PTD:201-086 LIilcorn Alaska.LL, API:50-029-23017-00-00 a. Do not exceed 1500psi on the tubing (tree side) and 6500psi on the hanger void. The combined load can cause damage to the load shoulder on the tubing hanger. b. Do not allow the tubing hanger void pressure to exceed 5000psi above the tubing (tree side) pressure. The tubing neck seal is a flex seal and has a rating of 5000psi differential from below. c. Bleed all pressure off the tubing hanger void and the tree. 11. Rig up BPV lubricator and pressure test to 4000psi. 12. Pull TWC. RD from well. Operations—Once well is on stabilized injection (within 2 weeks of putting online) 13. Contact AOGCC for witnessing of MIT-IA (24 hour prior notice required). r� 14. RU triplex to the IA and conduct MIT-IA to 2700psi. a. Required test pressure is: 0.25 x TVD of packer (0.25 x 10,484' and = 2621psi). Attachments: As-built/ Proposed Well Schematic/Tree&Wellhead Diagram/AOR Map NS13- 5K VELLHFAD= ABB-VG 13-5/8"A T�30VNL 5K SAFETY NOTES: °°WELL REQUIRES A SSSV'°° i CHROME TBG&LNR"" C11JATOR= BAK 11IAL KB.ELE 56.19' I F.ELEV= 4029'(CB 15.9') OP= 2363' 1997' —4-112'HES SSSV lax Angle= 31 - @ 63544' w/1-1X0 SLV NP,D=3.813" ' atum ND= 11299' etum1VD= 10500'5S 13-3/8"CSG,68#,L-80 BTC,ID=12.415' H 3198' • t,,,,-/`a(,0-' GAS LIFT MANDRELS (N v ST MD TVD DEV TYPE V LV'LATCH PORT DATE Minimum ID =244"@ 11663' QJ 1 5161 4910 30 SMOR DMY BK 0 11/28/01 4-1/2" X 2-7/8" QCLL PKR PATCH I TOP OF 7"LNR —i 9900' J iri 9900' —19-5/8"X 7'Lls,R TOP PKR,D=? 9-5/8"CSG,47#,L-80 BTM-C,13=8.681" H 10083' , ` 11178' H4-1/2"CORA PT GAUGE,ID=3.813" I I 11200' —14-1/2"HES X NP,D=3.813" Lv (II 11222' —17"X 4-1/2"BKR PERM PKR,D=3.875" 11246' —14-1/2'HES X NP,D=3.813" I,i'—'I r1 11257' —4-1/2'HES XN NIP,ID=3.725' (11258'ELM 0) 4-1/2'TBG, 12.6#,13CRVAM-ACE, 11270' ` .0152 bpf,D=3.958' 11276' Hr X 5"BKR LNR TOP PKR,0=? TOP OF 4-1/2'LNR —1 11276' ) 11270'.1-14-112"WLEG,D-3.958" 7"LNR,26#,L-80 BTC-M,.0383 bpf,D=6276" —1 11488' 1 ,4 11292' —I SMD TTL1 R 04/01/07 11290' —17"X 5"BKRR LNR HGF,D=? 11299' —15"X 4-1/2"XO,D=3.958" PERFORATION SUNM4R1' 1165T -J 45 KB PKR w/2-7/8"QCLL STINGER, REF LOG: LWD-Vision Resistivly 11/18-20/2001 ID=2.41"(04/17/14) ANGLE AT TOP PERF: 4°@ 11856' � Note:Refer to Production DB for historical pert data gl m---111663'-11866' 4-1/2'X 2-7/8'QCLL SWELL PKR PATCH SIZE SPF INTERVAL(ND) Opn/Sgz SHOT SQZ -� I ID=2.44"(06/03/13) 2-7/8° 6 11724-11864 S 12/01/01 03/17/07 its , 2-7/8" 6 11834- 11864 S 01/20/05 03/17/07 0 2-7/8" 6 11856-11874 0 04/16/07 2-7/8' 6 11859-11885 S 01/19/05 03/17/07 . 2-7/8" 6 11866-11886 0 03/17/07 53 )t 5 61' 2-7/8" 6 11874-11894 0 04/08/07 2-7/8" 6 11876-11886 0 04/01/07 2-7/8" 6 11880-11890 0 04/01/07 11915' —1 FETID 4-1/2"LNR, 12.6#,13CR VAM-ACE, —1 11975' .0152 bpf,ID=3.958" DATE REV BY COMu NTS DATE REV BY COMVB'ITS NORTHSTAR 12/02/01 JAS RNAL COMPLETION 05/29/13 SET/PJC SET QCLL ANCHOR(5/27/13) WELL: NS13 04/08/07 SGS/PAG ADFERF 06/11/13 WEGJM)SET SWELL PATCH(06/03/13) PERNIT No: 2010860 04/26/07 1;1+11/11H ADFURF(04/16/07) 04/18/14 JG/PJC SET 45 KB PKR(4/17/14) AR No: 50-029-23017-00 11/27/07 VCR/PJC WEIFEAD LOCATION 04/19/14 PJC PERFORATION CORRECTIONS SEC 11,T13N,R13E, 1169'FSL&644'FR. 06/28/08 WRRPJC DRAWING CORRECTIONS 02/17/11 M3/JND ADDED SSSV SAFELY NOTE BP Exploration(Alaska) • • NS- 13 o 9-22- 16 J ( Swab Vetco 5-1/8" 5M (uprated to 6500psi) Companion Vetco 3-1/8" 5M .0'.j`-�� 'PLI'9111 (*v.: % 11 iNV'tt,' ,, --7, - i 40' ,.- '''''*' 1 jr- � Wing Vetco 5-1/8" 5M (uprated to 6500psi) / SSV Vetco 5-1/8" 5M (uprated to 6500psi) 0 \ _,__,___________/, i Flowcross Vetco 5x5x5x3" 5M i Master Vetco 5-1/8" 5M (uprated to 6500psi) I v V I r • RrAA -u II Ili Ll J V ( I S 1� of — `'I I :::_I. 4 _:::11 I ll- rill — _I 2 i o ® 111114 -rIiP 4111- 111 III NS- 13 • • 9-22- 16 ,,n) -iL -- Ifiifurp Aismka,LLC Proposed ,,, Swab Vetco 5-1/8" 5M (uprated to 6500psi Companion Vetco . 8" 5M i : _, � L%. (uprated to 6500) _ di 0 0 po, :_ip ' 4, ' 0 ", PAA') in] i I,,,, '4 0 Wing Vetco 5-1/8" 5M (uprated to 6500psi) SSV Vetco 54/8" 5M (uprated to 6500psi) 0 Flowcross Vetco 5x5x5x3" 5M (uprated to 6500) r.-:-.1,..,-...) X 1 , , , .. , cA,k,5- /- c' • Master Vetco 5-1/8" 5M (uprated to 6500psi) ,�'Y " ```-'"- _I ' 1 , - 11 N ;:;:� 4 :moi�� 4 is) ; - II •:..,. ' ■ I:::: .- uu 1 si i , --, , . , .. , - , 1 1.14 _ , p _ -tI 10 4111- a II ■ 1 r ■ • • w U L J CO J M L 0 '6 (n Z Q g 6, ^' Q mW d N (nL N p Q o I- W E m - ' M> W Y O o av Q o - d- a t O W J6 o OC ,N - Q W2N.tN E .mc 0 p M p v v zj N a d-3� (N am ( oa m mqo`JZ d OU I c 11t • 2E2-2 Y NQmm fn ,-.>-o CO >N2NN O- Q CW CVo NM 0, C Z Z N Z ' Z a / .• iCO co . 11t ' �-- Zo _ '111.111.111110111111111111111arler Ala < Verd _1 4 imp*, LLI CO TN � N LO Igr KI j 0...- a CO Z / , j-co N Z N IA/ r-- Z u) - ,/:! lr, 7 . ri . 1 1 aii z ,41 I It 1 ..„,. ...1 i CO• tm N / I r Z j Cl). 4 co 1 Z Z Z / C r <1 ,,, W .. r NI / STATE OF ALASKA RECEIVED , AL.,,oKA OIL AND GAS CONSERVATION COMM,__JION MAY 0 9 2014 , REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations LJ Perforate LJ Other L p Performed: Alter Casing ❑ Pull TubingJ Stimulate-Frac ❑ Waiver ❑ Time Extensions Change Approved Program ❑ Operat.Shutdowns Stimulate-Other ❑ Re-enter Suspended WOO 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: I Name: BP Exploration(Alaska),Inc Development El Exploratory ❑ 201-086-0 . 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-23017-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312799 NSTR NS13 . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NORTHSTAR,NORTHSTAR OIL 11.Present Well Condition Summary: Total Depth measured 12000 feet Plugs measured None feet true vertical 11255.78 feet Junk measured None feet Effective Depth measured 11915 feet Packer measured See Attachment feet true vertical 11170.96 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor #REF! #REF! #REF! #REF! #REF! #REFI Surface 3154 13-3/8"68#L-80 44-3198 44-3177.96 5020 2260 Intermediate 10039 9-5/8"47#L-80 44-10083 44-9345.35 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 43-11270 43-10527.19 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer 1996.94 1997 1996.94 SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED MAY 2 9 2014 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 189 21758 18 0 2449 Subsequent to operation: 195 27757 126 0 744 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run ExploratorE Development❑, • Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑✓ • Gas U WDSPLI GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-107 Contact Analisa Steger Email Analisa.Steger(a�BP.Com Printed Name Analisa Steger Title PDC Data Manager Signature ).,,,,„„c„.;-..._, . 4„r Phone 564-5439 Date 5/9/2014 ULA 5/z a /if RBCMS MAY 14 Z 4 Form 10-404 Revised 10/2012 ".", f/204 Y Submit Original Only � W CO w CO w w w w -. -' N NJ N NJ N - ---- - 0) W A W CONJ O CO - . 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W- r w CO c (C2 060 & c? o0) D aoO0 v O O r o _ C#4 . - Co — CO CD/� r+ I I I I v W ra n N) CO CO A O CO - co) oD0) O 0 01 OD CO 0- 0 CO A A w CO A A O W CD -I 1 I v 0 W rn CT ) N -I A N -I N) CO A CIS N O A Co CO N) C) - CX) v 01 O CO Cli co A CO A CD A N 0) N C W N W A -1 0) O O 0 O O O O U • C) CJt A N O 01 N) 0) Ut A �I CT - O 0) O C) co D) O O O O O O y co Packers and SSV's Attachment ADL0312799 SW Name Type MD TVD Depscription NS13 SSSV 1997 1996.94 4-1/2" HES HXO SSV • NS13 PACKER 9900 9164.25 7" Top Packer NS13 PACKER 11222 10479.3 7" Top Packer NS13 PACKER 11276 10533.17 5" Baker ZXP Top Packer NS13 PACKER 11657 10913.44 KB Liner Top Packer Z Z Z Z Z Z Z Z Z Z Z 3 m 0 A A A A A A A A A A W M MMMMMN N N N N N N N N N N 0 0 0 0 0 0 0 0 0 0 0 C o 0 o O o o o 0 0 a DDDDDDDDDCi) (/) `�° -D -D -a -a -a -a -a -a -0OO � 1'1 TI T1 TI -n -n TI TI MNN 5 0 0 0. fD .� CD 0 N —s y D ,moi, p co 0o co- co co co co co co CO v 0 Li • c0 Oo Oo v v O) O) O) (n W N 7 r 0 0) O 0) A O) A OM A A = 0 0 -0 V rF 3 � • 3 y0 CD w ( w0) Oo -JOow001ODv• rr co c0 Oo 0o v v 0) W O 01 W AOrnO0Aa) AO0A w N p O (0 - A W W W N N (0 O m N O Ni O N O O) N O O • W O O O O O O O O co N W A (T 0) O) -I N N a O - A W co co N N — (0 -p: 01 A N O) N O V O O) Nom) O s. 0 0) 0 0 0 0 0 0 0 0 ED -- N W A (T O) O) —1 N w 0 fD TREE= ABB-VGI5-1/8"S WELLHEAD= ABB-VG 13-5/8"MULTIBOWL SKDI N S 13S Y NOTES:"..WELL REQUIRES A SSSV"' ACTUATOR BAKER 4-1/2"CHROME TBG 8 LNR— o NTIAL KB.Ell 56.19' I I BF ELEV= 40.29'(CB 15.9') KCP= I 1997' 4-1/2"HES SSSV Max Angle= 31°@ 6354' O w/HXO SLV NP,D=3.813" Datum M3= 11299' Datum TVD= 10500'SS 13-3/8"CSG,68#,L-80 BTC,D=12.415' 3198' GAS LFT MANDRELS . ST MD TV D DEV TY PE V LV LA TCH PORT DA TE Minimum ID = 2.44" @ 11663' I I iI 1 5161 4910 30 SMOR DMY' BK 0 11/28/01 4-1/2" X 2-7/8" QCLL PKR PATCH � TOP OF 7'LNR —{ 9900' 4r 9900' H9-5/8"X 7"LNR TOP PKR,D=? 9-5/8"CSG,47#,L-80 BTM-C,D=8.681" 1 10083' L. 11178' H4-1/2"CIDRA PT GAUGE,ID=3.813" I I - - 11200' —14-11r FES X M',D=3.813" X v 11222' H7"X 4-1/2"BKR PERM PKR,13=3.875" /�I ' 11246' H4-1/2"HES X NP,D=3.813" ' , 11257' 4-112"HES XN NP,D=3.725' (11258'ELM D) 4-1/2"TBG,12.6#,13CRVAM-ACE, 11270' .0152 bpi,13=3.958" 11276' H7"X 5'BKR LNR TOP PKR,D=? 11270' �4-1/2"WLEG,D-3.958" TOP OF 4-1/2"LNR H 11276' 7"LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276" H 11488' 11292' HELM)TT LOGGED 04/01/07 11290' H7"X 5"BKR LNR HGR,D=? 11299' —15"X4-1/2"XO,ID=3.958" PERFORATION SUMMARY 1165T —45 KB PKR w/2-7/8"QCLL STINGER, FIEF LOG: LWD-Vision Resistivity 11/18-20/2001 D=2.41"(04/17/14) ANGLE ATTOPF : 4°@ 11856' ._. Note:Refer to Production DB for historical perf data _. 11663'-11866' 4-1/2"X 2-7/8"QCLL SWELL PKR PATCH SIZE SPF NTER'VAL(MD) Opn/Sgz SHOT SOZ C)=2.44"(06/03/13) 2-7/8" 6 11724- 11864 S 12/01/01 03/17/07 2-7/8" 6 11834- 11864 S 01/20/05 03/17/07 , 2-7/8" 6 11856-11874 0 04/16/07 2-7/8" 6 11859-11885 S 01/19/05 03/17/07 2-7/8" 6 11866-11886 0 03/17/07 El 1.7; 2-7/8" 6 11874-11894 0 04/08/07 , 2-7/8" 6 11876-11886 0 04/01/07 I 2-7/8" 6 11880-11890 0 04/01/07 I — — 11915' H MID 414.1.4 4-1/2"LNR 12.6#,13CR VAM-ACE, — 11975' kt1w.w.w.w., .0152 bpf,ID=3.958" DATE REV BY COM.UJTS DATE REV BY COMMENTS NORTI-6TAR 12/02/01 JAS FINAL COMPLETION 05/29/13 SET/PJC SET QCLL ANCHOR(5/27/13) WELL. NS13 04108/07 SGS/PAG ADF'ERF 06/11/13 WE YJM)SET SWELL PATCH(06/03/13) PERMIT No: 2010860 04/26/07 F2 4-VTLH-ADFB(04/16/07) 04/18/14 JG/PJC SET 45 KB R(R(4/17/14) AR No: 50-029-23017-00 11/27/07 VVRRIPJC WELLI-LAD LOCATION 04/19/14 PJC PERFORATION CORRECTIONS SEC 11,T13N,R13E,1169'FSL&644'FEL 06/28/08 WRR/PJC:DRAWING CORRECTIONS 02/17/11 MB/JM3 ADDED SSSV SAFETY NOTE BP Exploration(Alaska) ,e-,\\\1//77 �� THE STATE d Gas or A 333 West Sevenin Avenuc Anchorage Alaska 9950 3572 GOVERNOR SEAN PAK:��ELL vc �0. 7 ._v 79 1433 / 276.7..' Mark Sauve Petroleum Engineer O 006 BP Exploration (Alaska), Inc. F P.O. Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field,Northstar Oil Pool,NSTR NS 13 Sundry Number: 314-107 pHNED AUG U 6 ZDlik 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, Cathy P. oerster /� Chair ..,, QQ7 — DATED thisl.,O day of February, 2014. Encl. LVED STATE OF ALASKA FEB 2 4 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION D7S 212-01/I— APPLICATION FOR SUNDRY APPROVALS ADCC 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❑ LLTiime Extension❑ Operations Shutdown El Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: t�8elEerppSet ❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Development Q . Exploratory ❑ 201-086-0 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23017-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 458A NSTR NS13- Will planned perforations require a spacing exception? Yes ❑ No El • 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 ND(ft): Plugs(measured): Junk(measured): 12000 • 11256 • 11910 - 11166 ' None None Casing Length Size MD ND Burst Collapse Structural Conductor 116 20"169#X-56 45-161 ND Top-ND Base Surface 3154 13-3/8"68#L-80 44-3198 - 5020 2260 Intermediate None None None None None None Production 10039 9-5/8"47#L-80 44-10083 - 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment • See Attachment 4-1/2"12.6#13Cr80 13Cr80 43-11270 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths 4-1/2"HES HXO SSV , 1997', 1996.94' 12.Attachments: Description Summary of Proposal ❑ 113.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: 3/3/14 Oil Q• Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ l17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Email Mirk. a -0.13' om Printed Name Mark Sauve Title Signature Phone Date ��� 564-4660 2/24/2014 COMMISSION USE ONLY J Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\`' .— \01 PlugIntegrity BOP Test Mechanical Integrity Test Location Clearance I 9tY ❑ ❑ e9tY ❑ ❑ RBDMSMAY n AY .1 0 2014 Spacing Exception Required? Yes ❑ No LY Subsequent Form Required:P 9 P 4 4 q Id 40 4- APPROVED BY Approved by: �i,_.` COMMISSIONER THE COMMISSION Date:Z - ZE—/GL PprO /alp�a NA hs f P12S'I1 pP Duplicate 10-403 'evised 1/2010 A d months from the date of approval. Submit in Du licate VLF 2/2 7/14 /ter ° ALASKA WELL ACTIVITYSTATEMENT OF REQUIREMENTS(V1.2 DBR,LHD 11/20/13) General Information Well Name: NS-13 Well Type: NATURAL FLOW PRODUCER Activity Description: GSO Well Activity Classification: CONVENTIONAL 4 Field/Reservoir: NORTHSTAR Cost Code/AFE: ANSNRWOS Job Type: GSO-LTP 12 Month Avg 10R,bopd: 10 AWGRS Job Scope: PROFILE MODIFICATION Estimated Cost, SM: Sundry Form 10--403 Reqd7 Yes Sundry Form 10-404 Required? Xes Other regulatory requirements? APM from BSEE Primary Secondary Base Management Engr: Mark Sauve Contact numbers: (907)564-4352 (907)748-2865 Well Intervention Engr: Bethany Free! Contact numbers: (907)564-4661 1907)378-6493 Lead BM Engineer: Mark Sauve Contact numbers: (907)564-4660 I (907)748-2865 Date Created: February 17,2014 Revisions(date,who,what changed): Current Well Stade Information Current Status: Operable Recent Well Test or Injection Rate and Pressure: 02/09/14 1181 bopd 1 112 bwpd 126 6 MMscfpd 1146,715 GOR 1165 beans] 741 pc: No GL Recent H2S(date,ppm) 6/13/2009 17 ppm If inoperable or under evaluation,why? N/A Datum depth,ft TVDss 11,100'TVDss Maximum Deviation(angle and depth) 31° 16,354'MD Reservoir pressure,psig 5,113 psi Minimum ID and Depth 2.44'@ 11,663'-11,860'MD Reservoir temperature,F 253°F Last downhole operation(date,operation) SL-6/3/13 Set 4.5'R-lock with OOS in SLVN @ 1961'SLM. Shut in wellhead pressure 3,885 psi Most recent TD tag,(date,depth,toolstring OD) SL-5/15/13 Drifted w/3.6'centralizer and Tag TD @ 11,899'ELMD(corrected) Known mechanical integrity problems(specifics) None Comments,well history, NS13 was completed in late 2001 and is a high GOR well from early in life.In an attempt to make this well a competitive,low GOR producer,it was squeezed and reperfed in March 2007 but background information,etc: the GSO failed to make a significant improvement to the producing GOR. A follow-up P-prof in July 2007 indicated the squeeze to be leaking gas in two separate places. In May 2013 a GSO attempt was executed using segmented swell packer elements with snap latch connections that are fully slickline deployable but since that time the GOR iron NS13 has returned to previous levels and it is suspected that the patch is leaking. It is the intent of this program to detemine if the_pa4ch is leaking,specifically allowing gasgu_the backside of the patch ar,Ld if so then to deploy a liner top packer to shut off that leak path. Well Intervention Details Suspected Well Problem: (High GOR at present Specific Intervention or Well Objectives: 1 Determine if the GS0 patch deployed last May has failed and if so where the major gas entry points are. 2 Deploy a liner top packer(LTP)to the top of the liner patch if the logging results indicate that by doing so the primary gas entry point would be isolated. >/ 3 Key risks,critical issues: Mitigation plan: 1 Real-time log interpretation accurately identifiing the primary gas entry point. Have PE's standing by to interpret log and decide on LTP deployment without rigging down a-line 2 Successfully deploy the LTP Run dummy LTP prior to deployent&have LIP service hand on site for actual deployment. 3 Successfully deploy the SSSV. Summary Step# Service Line Activity 1 S Pull SSSV,D&T for logging tool deployment and run dummy LTP to ensure seals will engage fully if real LTP is run 2 E Run P-prof into liner,determine primary gas entry point(s) 3 S Deploy LTP into top of liner patch if P-prof indicates a high likelyhood of GSO success. Re-run SSSV 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 425 MMSCFD 25 BWPD 175 PTP(psi): 750 Choke setting: 176 Post job POP instructions: 1 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: PRODUCTION PROFILE V„o 0210/02/13 Well: NS-13 Prop.Code: GSO•LTP CC or AFE:ANSNRWOS API#: 50-029-23017-00 Name:Mark Sauve(Nstr PE) Contact numbers: 907-564-4660(H) Proc.Dist. Date: Contact numbers: 907-748-2865(M) Town: Contact numbers: APE Well File Objectives(In order of importance): Slope: Determine primary gas entry point(s) W/L(3) Deploy Liner Top Packer if primary gas entry point is determined to be at top of patch(coming from backside) FE Logging Notes: Velocities are potentially very high inside of 2-7/8”liner patch. Well will need to be severely choked to prevent being blown up hole.. Accurate 3-phase splits are not the primary objective,we just need to know if there is a large gas entry at top of patch indicating flow from backside •Make sure welt is in test during logging and attach WS30 Tie-In Log: Memory GR/CCL Co. Schlum Date: 3/31/2007 Tie-In Method: @ Min ID: 2.44"in 2-718"patch @ 11,663-11,860'MD Stable Producer? yes Produce For: 0 days before logging. Gas Jetting Expected? Yes Expected H2S: 7 ppm Date of Last PPROF: 7/14/2007 Last Tag: 11,899 ft ELM/SLM. ELMD RH/Fill Date of Tag: 5/15/2013 FCO if tag above: 1)RIH with: GR/CCL/TEMP/PRESS/DUAL SPINNERS 0.0° 2)Other Info: Well produces 55+MMSCFD of gas at full open choke. PPROF Logging Summary-Tie-In Log:Schlumberger GR/CCL dated 1-12-02 Pass Direction Speed(fpm) Depth(ft,md) Notes PPROF Flowing Pass Up/Down 40 11,550'-TD Well Flowing Flowing Pass Up/Down 60 11,550'-TD Well Flowing Flowing Pass Up/Down 80 11,550'-TD Well Flowing Stop Counts Stops - 11,600 Well Flowing 11,710 11,800 11,850 Jewelry Log Up 80 TD-11,000' Well SI LOG PRESENTATIONS 1.Job Comments—operating steps in sequence,flow rates for logging passes and basic field interpretation including production and injection splits. 2.Flowing Overlay—Spinner,temperature and pressure data from the 60 fpm up passes. Presented on a 5"/100ft. Note flow rates for flowing pass in log header. 3.Flowing UP Pass Overlay—Spinner,temperature and pressure for 40 fpm,60 fpm,and 80 fpm passes. 4.Flowing UP/Down Pass Overlay—Spinner,temperature and pressure for 60 fpm passes. 5.Production/Injection Overlay—Spinner,temperature and pressure for 60 fpm up passes. 6.Baseline Injection/Borax Overlay 7.GHOST Log • FBI AB3-V(35-113'51(01 Y161-I454.14= AIX}V6113-RFM-L118&311!VLSI N S1 3 SAC111404148 TB6 LLR"'ROWNEYA 936Y^• ACRM1p1= MAL KB OA 56.11 001' 2363' --I1997' H4-1/7ries 3001 I Anala- 0•'a MEW41111 !r1t6C09LY NP,D-1.611" 11118143 ..... ....._ -_.._4178Y 114u111VD 10500 SC .13 L8'CSG,NW L 600TG O-12415' 914P CA9 LIFT M4tp3_ .3 4Tj ►C 1VI)/73Y:TYPE V V •1'211 Gro i- s I Minimum ID=2.44"a 11663' 1,1161 0113 All ,SMK1 1.10 .. ,...- 4-12'X 2-718"QCLL PKR PATCH 11411cN)-LVK hi wow _ { 9100' len x/'LAA itm,FratU /_.. !P516'CSG,474.L1A67MG0-0.000 -110911131 1117$' L VP CEPA PT SALM.C-U41'Y� 11200' 4.112'ICS X RP,O-181.' 11222' H7'X 41,2'OKR FERIA PCR D-3075- I • 11240' 4 1/2'IM0 X rJP,D-1.81°" II A 1,-1BR 17M 014E VA M.A(:F, 11270' 112 112S0'ELlAOj -14-td2'tEO XN'P,D-3.T':' 41884/6 ',0.52bpf,C..1,658' 11278' H7•x S"tb62 LM3 TOPPKR O-7 ill 011 'aoa-;iifl"iMi-1—(- 111/6' I li�. 11270' --1'4 117atm D 3858'1 11217 H14141 0 400011104/0/10/ IPLML28f.L-OCDTGM 9061 bo/.D-6 711, � 11468 ; 11200' }-',1 X 5.16112LNR,OR,O-21 11268• Hs-x4-vDX0,tt-0656') PERPOPATICP.341.116ARY M, 11663' 1 4.117x1-716'out 5Y'Ei.t.4112 ea ICN: 14+101*11Y)V84or 1.616846 11118 ;AMI001 1, 0-2.44'i06g13t/3) ANCTF ATITPPFBF 4"OI11850' j MAI.Re(e'M P1a.1eclir,130 foe 111401(:41 pelf*Gs t C Al 4-/AT! 15 111/24-11864 5 Wit/WI, ' 2-31'1 8 111814-11664 3 80/1707 7/AT'' 6 1 11616 118/4 0 04/64/04/16/1/C 2.7.81 2-7/6`. 0 I 11109-11060 3 03/170/ 001$1/ 1--{•-4/r(x2=arel',ti¢Xx 10-?a<I-.wra oll7 2-v6'; 6 111074-11001 0 01X18/61,00/07 ' 2779" 8 ;11080 11800 0 0401X:7 0410107 . I , ',R3TD H 11916 �•t II4-1,2'INK 12.08.13CR VAM-ACE, - 11975 l..•%11 .0152 64*,0-).11662 DCl 711EV BY CCMOBS CATE REV 03 CJIwas VDRD6tAR 1wool' JAS RIf1L COMPLETION 35129213 SLTIPJC SCT OU.L 4)621314 152/213) PALL 3013 04416'07'91R40 AIIFFRF 36/11/13 VKT:JM)':FT rmart 11102 M701/0641111 MAP/L X110060 04126'071 14641L14 A1IFE21(04/1607:. Aft No-53-0'19-23617.00 11/27'S? WQYPJC 10111.I4TID LOCAMN SIM 11.T1314 R13C 1189'tOL&644 FC'. 06/28'06/WaYPJC CRAVAM.00f0CCf01t —_ 09117'17, 1,4)91) ArTY1)ASSY SAIFTY NUTF 6P Bglnratun 4Abata) • Minilog for Well Techl©g Project NORTNSTAR NS13 Curd:LAURA.).LARSON Scale 1005 Date 1131/2013 Producer Well:N513 UM 3003102.101700 ....enn.!CID x:656651.03 USA Shod name Mal Extuattan datum idl r 0331•80.33 o�:« ' ;;:°oNdateoo:oo R Mme.NOR1NSTAR No Id 1.01 Coo.e.....,..m NAo3T ArT Lat..»..9107, Status' EMMA .. ,.... (CLOS IR) PE Notes - i roes aero �......a 1:100 L:soo 3 "'A/I%`"" "`"KFC""" .. SWT ,.,MMT 0/WIG ....._ •Lw • {{ os� Ls1 . .1 N 46/0/60 — 1 i .,., a 1....... . ., :o—ILS -'la• . .. 10/0/29 MP Cl. aaa_L,.00. L_. a/0/11SOP ,at eo—I.. 311 La — 1 NE= 11100-•11900 • .111$1,-11950. dow.t. • . .Yvr.,,.�`/r""✓refFr'r,P,'YYf" .gf,r,i fSr.,"'i f,'.?,ZT%.'t:t.,'x11`%.; Conventional 1 Production! ;: �;�:??'�.F.,a '4r4i °',r i s>)r.a yo-,.. Asa x+,"+,#i. ,,.° >w'�" ."r t,^.;x:'? i�!�,, .✓„4.,'ah �.*,t s.. A. a,a *t.. ! .,,. -_>. ❑ Subsea(Wet Tree-Semi Submersible, Intervention Vessel) or Offshore Under-balanced U Well rate 15 mboed for 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/flow assurance challenges. mboed(30 mmscfd')." ❑ Technology/Technique new to Industry. U Activity costs as per Well Activity performed on a Tier 1 or Tier 2 well, defined in GWO Wells Classification Regional VP Resource (UP 4.1-003) Delegation of Authority (DoA). Conventional 2 Production/ Conventional 2 Complexity Criteria Regional DoA Criteria U Single or multiple element integrity test failures with identified moderate potential to U Well rate ?3 mboed and 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 S5 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 Offshore Platform Rig (Dry Tree), Offshore Jack-up Rig (Dry Tree), Offshore Hydraulic Management Manager Workover Unit(Over-balanced operations), Land Drilling Rig. Delegation of Authority ❑ Technology/Technique new to BP. (NAL Conventional 3 Complexity Criteria Conventional 3 Production! Regional DoA Criteria ❑ Single element well integrity failure is known to exist or uncertain integrity status with U Well rate 3 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 Weil Activity history but report of failed tree valve. mmscfd') or Incremental • Dynamic but well understood reservoir or wellbore conditions with well understood added/restored production production chemistry issues (e.g. hydrates, scale, wax, asphaltenes). Addressed by % 0.25m boed and : 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 ❑ Activity costs as per track record)that effectively manage the impact on the planned Well Activities. Regional Base ❑ Management Team Lead Land operations with a Hydraulic Workover Unit(Over-balanced operations) Delegation of Authority ❑ H2S concentration in reservoir/wellbore fluids> 10 ppm, partial pressure H2S>0.05psia (DOA) 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 (SIMOPS):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. U 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 impacts,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 = 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. 0.25mboed/12 months ❑ Static or benign reservoir or weilbore conditions with no significant production chemistry (1.5 mmscfd')." issues which might impact the planned Well Activity. U 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 "Added/restored production refers to average over following 12 months Perforation Attachment ADL0312799 Well Date Perf Code MD Top MD Base TVD Top TVD Base NS13 3/17/07 SQZ 11724 11834 10980 11090 NS13 4/16/07 SQZ 11834 11856 11090 11112 NS13 4/16/07 APF 11856 11860 11112 11116 NS13 4/16/07 APF 11860 11864 11116 11120 NS13 4/16/07 APF 11864 11866 11120 11122 , NS13 4/16/07 APF 11866 11874 11122 11130 NS13 4/8/07 APF 11874 11876 11130 11132 NS13 4/8/07 APF 11876 11880 11132 11136 NS13 4/8/07 APF 11880 11886 11136 11142 NS13 4/8/07 APF 11886 11890 11142 11146 NS13 4/8/07 APF 11890 11894 11146 11150 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED I 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 0 0 -0 CO Cb C) C O CLO C0 U COiCO CO U X CO J J J CO a) Q 0 0 0 0 0 0 N6) O r- co co O — crr` N LO p N I� N N- U 0 0 0 0 0 0 CO M N- N M N V N CO O NI- M m V CO r` (O CC) CO N G) Cn Cn C6 (d M m ❑ ❑ > > H Q Q O 0 H ❑ ❑ i H CO O) E O) a) C LO CO CY) O C O ��/�D CO (0 Oa) .1- O _ N J cn o Q CO o COH Ln r N d- CO U ❑ v v 2 O CO CO i °? U r CU I# *k J 0c0 N (.0 *k 4- o (o co N O N N =(.:0 CO CO N N Cn , CA i L L_ 0) 0) c c N CV J J c O O w • D D Q U (13 U ❑ IYc ❑ LLZ Q Z_ Z_ cK D j 0 J J D Cl) H Packers and SSV's Attachment ADL0312799 Well Facility Type MD Top Description TVD Top NS13 SSSV 1997 4-1/2" HES HXO SSV - 1997 NS13 PACKER 9900 7" Top Packer 9164 NS13 PACKER 11222 7" Top Packer 10479 NS13 PACKER 11276 5" Baker ZXP Top Packer 10533 STATE OF ALASKA - ,. AKA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U . Plug Perforations Li Perforate Lf Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WelI 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development al . Exploratory ❑ 201 -086 -0 • 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23017 -00 -00 . 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0312799 NSTR NS13 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 12000 feet • Plugs measured None feet true vertical 11255.78 feet Junk measured None feet Effective Depth measured 11910 feet Packer measured See Attachment feet true vertical 11165.96 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 116 20" 169# X -56 45 - 161 45 - 160.99 4260 2590 Surface 3154 13 -3/8" 68# L -80 44 - 3198 44 - 3177.96 5020 2260 Intermediate None None None None None None Production 10039 9 -5/8" 47# L -80 44 - 10083 44 - 9345.35 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet 3 True Vertical depth See Attachment feet QED JUN 2 Z01 201 Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 43 - 11270 43 - 10527.19 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4 -1/2" HES HXO SSV 1997 1996.94 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 301 26586 201 0 2350 Subsequent to operation: 164 10898 272 0 725 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil U . Gas U WDSPIJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCEI 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 -027 Contact Nita Summerhays Email Nita.Summerhayst BP.com Printed Name Nita Summerha s , Title Petrotechnical Data Technician —/b- Sig •0 7: � � � /���� /��� / Phone 564-4035 Date 6/25/2013 lit f rRE3' \Ati JUN 26 206 Form 10-404 Revised 10/2012 Su ri ginal Only • • Daily Report of Well Operations ADL0312799 ** *COST PLACEHOLDER * ** 3/8/2013 purchase and assemble 6 swell packers ** *WELL SHUT IN ON ARRIVAL * ** (patch tubing /liner) TAGGED QOS SSSV @ 1961' SLM w/ 3.85" GAUGE RING PULLED QOS SER# QOS -17 FROM 1961' SLM 3/9/2013 ** *CONTINUED ON 3/10/13 WSR * ** * * *CONI INUED FROM 3/09/13 WSR * ** (patch tubing / liner) RAN XN LOCATOR & 2.50" SAMPLE BAILER LOCATE XN @ 11244' SLM ( +14' = 11258' ELMD), TIGHT SPOT @ 11706' SLM, S/D @ 11849' SLM ( +14'= 11863' ELMD) SAMPLE OF FLUID & WAXY SUBSTANCE RAN SLB TANDEM SBHPS GAUGES ACCORDING TO PROGRAM (GOOD DATA) ATTEMPTED TO RECOVER LARGER SAMPLE W/ 2.50" S. BAILER FROM 11849' SLM MINIMAL SAMPLE OF WAXY SUBSTANCE /UNABLE TO MAKE DEPTH FOR PATCH 3/10/2013 ** *WELL LEFT SHUT IN, WELL TENDER NOTIFIED * ** 3/14/2013 QCLL Patch Assembly CTU #3 Travel to PM2 bridge. Standby for escort to cross ice road. Wells Support took BOPs from CTU and rigged them up while waiting on escort. 3/27/2013 ** *Job continued * ** CTU # 3 1.75" coil, Job Scope: Mill XN nipple and clean out liner for liner patch deployment Travel to Northstar and RU CTU. 3/28/2013 ** *Job continued * ** CTU # 3 1.75" coil, Job Scope: Mill XN nipple and clean out liner for liner patch deployment Perform weekly BOP test. MU BKR left handed milling assembly w/ a 3.80" DPM. Fluid pack well w/ 5 bbl meth /wtr spear and 268 bbl 1`)/0 slick w/ safelube. Dry tag XN @ 11238' (ctm up). Attempt milling w/ no returns, WHP /CTP too high, take min rate returns to plant to reduce gas head on well. Get 2 motor stalls @ 11228', got lots of motor work higher @ 11223 - 11228'. Saw sudden CTP drop below free spin @ 11227'. Stack weight/no stall. FP coil, put 10 bbl meth /wtr down backside. POOH to inspect tools. 3/29/2013 Job in progress. CTU # 3 1.75" coil, Job Scope: Mill XN nipple and clean out liner for liner patch deployment Inspect BHA. Sheared /parted at disco. Left 15.26' of fish in hole. MU FCO assembly w/ 3.0" JSN. RIH and tag fish at 11227'ctmd. PUH 50' to 11177' and flag pipe. Come online w/ slick 1% KCI and clean out on top of fish, circulate gel OOH. Swap to 140F freshwater to prep for camera. Pump 100 bbl fresh from 11227'. FP coil. POOH, pumping pipe displacement while POOH. 3/30/2013 Continued on 03/31/2013 WSR. • • Daily Report of Well Operations ADL0312799 CTU # 3 1.75" coil, Job Scope: Mill XN nipple and clean out liner for liner patch deployment POOH from cleanout. MU Baker logging MHA, MU Expro camera. RIH to flag. Reset electronic counter at flag. Take video of fish. POOH. Recovered good video data. MU fishing toolstring w/ a 3.75" overshot and RIH. Sat down 3x on fish, POOH. No fish. Inspect BHA. Open up ID of lower portion of OS w/ die grinder. RIH w/ same fishing string w/ field modified O /S. 3/31/2013 * **Job continued 4/1/13*** CTU # 3 1.75" coil, Job Scope: Mill XN nipple and clean out liner for liner patch deployment Tag fish @ 11234' (CTM down). Get good overpulls, Get 3 down /2 up jar licks. POOH to inspect BHA. Pump 70 bbl safelube down backside. The overshot engauged the fish, but didn't hold on to it. MU & RIH w/ Tempress tool and a 3.38" ID overshot. Spot 6bbls of 12% HCI across fish. Sat down 5k and POOH. No fish, appeared to be about 7" over the fish. MU same Tempress /Jar string with new bulldog O/S sub run on 4" GS spear. Tag fish @ 11238'. Jar down twice up three times. Good overpulls, POOH while pumping pipe displacement down backside. 4/1/2013 Job continued on 04/02/13 WSR. CTU # 3 1.75" coil, Job Scope: Mill XN nipple and clean out liner for liner patch deployment POOH. Fish recovered. Cut 75' of coil. MU /RIH w/ new LH string w/ 3.8" string and parabolic mill. RIH and attempt to mill XN nip. Tagged down multiple times w/o any motor work. POOH to inspect BHA. MU /RIH w/ Right hand 2 7/8" motor, jars and 3.72" parabolic opticut mill. Dry tag @ 11858' (ctm down). Mill from 11853'- 11866' w/ 3 stalls, backream to 11620', mill from 11866'- 11896' w/ 2 - 10 bbl gel sweeps. 4th stall and bit stuck © 11896'. Have 19 down jar licks, weak up licks. 4/2/2013 Cycle coil and backside pressures. Continued on 04/03/13 WSR. CTU # 3 1.75" coil, Job Scope: Mill XN nipple and clean out liner for liner patch deployment Work stuck pipe @ 11886', Get 49 jar licks, break free, move down. Back ream up to 11630'. Run back in hole. Dry drift clear to new target depth of 11880'. Pump 10 bbl gel pill from 11880', circ bottoms up. RIH and dry tag at 11887', POOH. Cut 75' of pipe and change packoff. MU & RIH 3.7 "x20' liner patch drift assembly. Tagged down at 11890', drifted clean the entire way down. POOH. FP w/ 30bbls of 60/40 methanol. RDMO. 4/3/2013 * * * * * * * * * * * * * * * * ** *Job complete. * * * * * * * * * * * * * * * * * ** ** *WELL SHUT -IN ON ARRIVAL * ** STANDBY TIME WHILE VALVE /GREASE CREW SETS BPV & CHANGES OUT FITTING ON SSV OF NS -16 5/7/2013 ** *JOB CONTINUED ON 8- MAY - 2013 * ** • • Daily Report of Well Operations ADL0312799 ** *WELL SHUT -IN ON ARRIVAL* ** CONTINUED STANDBY TIME WHILE VALVE / GREASE CREW DOES REPAIRS ON NS -16 & NS -09 DUEL BARRIER TEST FAILED CURRENTLY STANDING BY FOR VALVE CREW TO INSTALL ASV ON WELL 5/8/2013 ** *JOB CONTINUED ON 8- MAY - 2013 * ** ** *JOB CONTINUED FROM 8- MAY - 2013 * ** (Eline set patch) RAN IN ELINE TOOLS W/ LOWER ANCHOR ASSEMBLY FOR CSG PATCH SET DOWN @ 11,250 FT (XN NIPPLE @ 11,257'), TOOLS HUNG UP AND UNABLE TO WORK PAST AREA. HAD TO PULL UP TO 2180# TO PULL FREE DECISON MADE TO POOH AND CHECK OUT TOOLS AFTER GETTING OUT OF THE HOLE THERE WAS HARD PACKED SCALE IN THE SLOTS & SLIP AREA OF BODY ON THE ANCHOR ASSEMBLY - NO OTHER IDICATIONS OF WHAT TOOLS WERE HANGING UP ON ** *DECISION MADE TO HAVE SLICKLINE RE -DRIFT & SET ENTIRE PATCH SECTIONS AT LATER DATE * ** WELL LEFT SHUT IN UPON DEPARTURE - NOTIFIED DSO AND CONTROL ROOM OF WELL STATUS FINAL T /I /O = 3800/15/13 PSI 5/9/2013 ** *JOB POSTPONED * ** ** *WELL SHUT IN ON ARRIVAL * ** (DRIFT PRE ELINE) CURRENTLY RIGGING UP SLICKLINE UNIT TO DRIFT PRE ELINE SETTING OF PATCH ANCHOR 5/13/2013 ** *CONTINUED ON 5/14/13 WSR * ** ** *JOB CONTINUED FRONT 5 /13(13 *** profile mod) RIG UP SWCP NS SLICKLINE UNIT 5/14/2013 ** *CONTINUED ON 5/15/13 WSR * ** • • Daily Report of Well Operations ADL0312799 ** *JOB CONTINUED FROM 5/14/13 WSR * ** (profile mod) RUN # 1 -- DRIFTED W/ BRUSH, 3.60" CENT/ 3.70" CENT BARBELL, SAMPLE BAILER (WORKED THRU & BRUSHED TIGHT SPOTS @ 11,221', 11,251' & 11270' SLM) - TAGGED HARD TD @ 11860' SLM (SAMPLE OF SCALE FLAKES) RUN # 2 -- DRIFTED W/ 10' X 3.70" DUMMY WHIPSTOCK - TO 11,831' SLM (TARGET © 11,866') UNABLE TO WORK PAST RUN # 3 -- DRIFTED W/ XN LOCATOR & 10' X 3.70" DUMMY WHIPSTOCK - TAGGED XN NIPPLE @ 11,228' SLM ( +30' = 11,258' ELMD), TAGGED TD @ 11,829' SLM ( +30' = 11,859' ELMD) (TARGET @ 11,866') - UNABLE TO WORK PAST RUN # 4 -- DRIFTED W/ BARBELL SETUP W/ 3.60" CENT, 2' X 1.875" STEM , 3.70" CENTRALIZER, 1.50" SAMPLE BAILER, SET DOWN IN SPOTS @ 11,830' & 11,850' SLM BUT ABLE TO WORK PAST WITHOUT TO MUCH EFFORT (WORKED THESE AREAS MORE UNTIL RUNNING THRU CLEANLY)TAGGED TD @ 11,869' SLM (11,899' CORRECTED) PULLED BACKUP TO 11,150' SLM AND RAN IN HOLE @ 50 FPM TO TD @ 11869' SLM ( +30' = 11899' ELMD) (TARGET 11,866' FOR ANCHOR) W/ NO BOBBLES SEEN (ALL CLEAR) WELL LEFT SHUT IN - CONTROL ROOM & WELL TENDER NOTIFIED WELL TO STAY SHUT IN FOR PATCH INSTALL AT LATER DATE 5/15/2013 ** *JOB COMPLE * ** ** *WELL S/I ON ARRIVAL * * *(E -LINE PACKER SET) INITIAL T /I /O = 3700/0/0. SET 4 -1/2" QCLL LOWER ANCHOR AT 11866', DID NOT TAG TD. DEPTH CORRECTED TO SLB MEMORY COIL FLAG DATED 31 -MAR- 07. TAGGED ANCHOR AFTER SETTING, NO TIGHT SPOTS NOTED WHILE RIH OR POOH. HAND OVER WELL TO DSO PRIOR TO DEPARTURE. FINAL T /I /O = 3700/0/0 5/27/2013 ** *JOB COMPLETE * ** T /I /0= 3800/17/14 Temp= SI Assist E -line ( set anchor ). Standby as 5/27/2013 contingency. ** *WELL S/I ON ARRIVAL * * *( profiie -mod) DRIFT W/ 3.70" CENT TO 4 -1/2" QCLL ANCHOR & TAG @ 11,829' SLM/11,860' MD ( +31' CORRECTION). NO OBSTRUCTIONS SET SECTION #1, 4 1/2" X 2 -7/8" BASE PIPE W/ 3 -1/2" x 34.20' SWELL PKR WRAP & QCLL SNAP LATCH IN ANCHOR @ 11,829' SLM (11,860' MD), 350# PULL TEST * *NOTE: THIS SECTION HAS A 2 -7/8" XN -NIP ABOVE THE SNAP LATCH ** 6/2/2013 * * *CONT ON 06/03/13 WSR * ** LRS Unit 38 Well Control Contingency for slickline. ** *WSR continued 6/2/2013 on 6/3/13 * ** • 1 Daily Report of Well Operations ADL0312799 LRS Unit 38 Well Control Contingency for slickline. T /I /0= 3600/0/0 Temp= SI Assist slickline, pump as directed. Pumped 5 bbls 40* Neat methanol through kill line down TBG followed by 50 bbls 44* Diesel followed by 5 bbls 40* Neat methanol cap. Turn well back over to Slickline, LRS back on well control contingency. SV= closed, WV= 6/3/2013 closed, SSV, MV = open, IA, OA= OTG ** *WSR continued on 6/4/13 * ** * * *CONT FROM 06/02/13 WSR ** *(profile -mod) SET SECTION #2 , 4 1/2" X 2 -7/8" BASE PIPE W/ 3 -1/2" SWELL PKR WRAP @ 11,802' SLM. 1200# PULL TEST SET SECTION #3 , 4 1/2" X 2 -7/8" BASE PIPE W/ 3 -1/2" SWELL PKR WRAP © 11,769' SLM. 1400 # PULL TEST SET SECTION #4 , 4 1/2" X 2-7/8" BASE PIPE W/ 3 -1/2" SWELL PKR WRAP @ 11,738' SLM. 1350 # PULL TEST SET SECTION #5 , 4 1/2" X 2 -7/8" BASE PIPE W/ 3 -1/2" SWELL PKR WRAP @ 11,703' SLM. 1400 I# PULL TEST SET SECTION #6 , 4 1/2" X 2 -7/8" BASE PIPE W/ 3 -1/2" SWELL PKR WRAP @ 11,669' SLM. 1400 # PULL TEST DRIFT W/ 3.84" NO -GO CENT & 4 -1/2" BRUSH © 1961' SLM SET 4 -1/2" R -LOCK & QOS IN SVLN @ 1961' SLM /1997' MD, 4 -1/2" QOS (ser# QOS -17, ctrl line operated, 3 sets of packing,) PASSING CLOSURE TEST ON SSSV LRS PUMPS 45 BBLS OF DIESEL DOWN TBG * ** NOTE: TOP OF PATCH 203' PATCH © 11, 663' MD 6/3/2013 ** *CONT ON 06/04/13 WSR * ** 6/4/2013 * ** WSR continued from 6/3/13 * ** Well control contingency for slickline * * *CONT FROM 06/03/13 WSR ** *(profile -mod) R/D SWCP DC #08 6/4/2013 ** *WELL LEFT S /I, WELL TENDER NOTIFIED * ** FLUIDS PUMPED BBLS 57 DIESEL 587 60/40 METH 1669 1% KCL SLICK 624 1% KCL SLICK W/ 0.6% SAFELUBE 56 POWERVIS 67 FRESH WATER 6 12% HCL 10 METH 3076 TOTAL Perforation Attachment ADL0312799 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base ND Depth Top ND Depth Base NS13 3/17/2007 SQZ 11724 11834 10980.32 11090.12 NS13 4/16/2007 SQZ 11834 11856 11090.12 11112.07 NS13 4/16/2007 APF 11856 11860 11112.07 11116.06 NS13 4/16/2007 APF 11860 11864 11116.06 11120.06 NS13 4/16/2007 APF 11864 11866 11120.06 11122.05 NS13 4/16/2007 APF 11866 11874 11122.05 11130.04 NS13 4/8/2007 APF 11874 11876 11130.04 11132.03 • NS13 4/8/2007 APF 11876 11880 11132.03 11136.02 NS13 4/8/2007 APF 11880 11886 11136.02 11142.01 NS13 4/8/2007 APF 11886 11890 11142.01 11146 NS13 4/8/2007 APF 11890 11894 11146 11150 BPS BRIDGE 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 • Casing / Tubing Attachment ADLO312799 Casing Length Size MD TVD Burst Collapse CONDUCTOR 116 20" 169# X -56 45 - 161 45 - 160.99 4260 2590 LINER 1568 7" 26# L -80 9920 - 11488 9183.98 - 10744.7 7240 5410 LINER 699 4 -1/2" 12.6# 13Cr80 11276 - 11975 10533.17 - 11230.8 8430 7500 PRODUCTION 10039 9 -5/8" 47# L -80 44 - 10083 44 - 9345.35 6870 4760 SURFACE 3154 13 -3/8" 68# L -80 44 - 3198 44 - 3177.96 5020 2260 TUBING 11227 4 -1/2" 12.6# 13Cr80 43 - 11270 43 - 10527.2 8430 7500 • • Y • • • Packers and SSV's Attachment ADL0312799 SW Name Type MD TVD Depscription NS13 SSSV 1997 1940.75 4 -1/2" HES HXO SSV NS13 PACKER 9900 9108.06 7" Top Packer NS13 PACKER 11222 10423.11 7" Top Packer NS13 PACKER 11276 10476.98 5" Baker ZXP Top Packer TREE= ABB- VG 5 -1/8" 5K• : IAELLFEAD= ABB-VG 13 -5/8' IYILTBOW. 5KSI Slay NOTES: "' WELL REQUIRES A SSSV"' ACTUATOR= BAKER N S 13 4 CHROME TBG & LNR"' NTIAL KB. FE 56.19' BF. E..& = 4029' (CB 15.9') KOP= 2363' 1997' I— 4 -1/2' HES SSSV Max Angle = 31' @ 6354' S w / HXO SLV NP, D = 3.813" Datum MD = 11299' DatumTVD= 10500' SS 113 -3/8' CSG, 68#, L -80 BTC, D = 12.415' H 3198' J - 4 GAS LFT MANDRELS ® MD gim DEV TYPE ® LATCH PORT DATE Minimum ID = 2.44" @ 11663' p 5161 4910 30 SMC)R DAY BK 0 11/28/01 4 -112" X 2 -718" QCLL PKR PATCH TOP OF 7' LNR I-1 9900' L ? — I 9900' — 19 - 5/8' X 7" LNR TOP PKR, D = ? I 9-5/8" CSG, 47 #, L -80 BTM-C, D = 8.681' H 10083' I — A • 11178' —14-1/2" CIDRA PT GAUGE, ID = 3.813' 11200' 1 4 -12" HES X NP, D = 3.813" 11222' — 17' X 4 -12" BKR PERM PKR, D = 3.875" 11246' —14-1/2" HES X NP, D = 3.813' 11257' (11258' ELMD) 1 FES XN MP, 13 = 3.725" 4 TBG, 12.6#, 13CR VAM - ACE 11270' \ .0152 bpf, D. 3.958" \ 11276' —17" X 5' BKR LNR TOP PKR, D = TOP OF 4 - 12" LNR IH 11276' I 11270' —14-1/2" WLEG, D - 3.958" 11292' H ELMD Ti' LOGGED 04/01/07 I I7' LNR, 26#, L -80 BTC-M, .0383 bpf, D = 6.276' —I 11488' • 11290' - 17" X 5' BKR LNR HGFR. D = ? I 11299' — " X4- 12 "XO,D= 3.958' I FITFOFZATON SUIMARI' I 11663' — 4 D - 112 = 2. 44 " X 2 - 7/8" QCLL (06/03/13) SWELL PKR PATCH REF LOG: DAD-Vision Resistivity 11/18 - 202001 ANGLE AT TOP F ERE: 4° § 11856' Note: Refer to Production DB for historical pert data SIZE SFF INTERVAL (M)) Opn/Sqz SHOT SQZ 2 -7/8' 6 11724 - 11864 S 03/17/07 2 -78" 6 11834 - 11864 S 03/17/07 2 -78" 6 11856 - 11874 0 04/16/07 04/16/07 2-7/8" 6 11859 - 11886 S 03/17/07 2-7/8' 6 11874 - 11894 0 04/08/07 04/08/07 : . .1.1860' �4 -1/2' QCLL ANCHOR, D = 2.45' (05/27/13) 2 -7/8' 6 11880 - 11890 0 04/01/07 04/01/07 I PBTD -j 11915' I 4 -12" LNR, 12.6#, 13CR VAM -ACS I 11975' .0152 bpf, ID = 3.958' GATE REV BY CO1vL 4TS DATE REV BY OOMbU4 S NORTHSTAR 12/02/01 JAS RNAL COMPLETION 0529/13 SET/ PJC SET QCLL ANCHOR (5/27/13) WELL: NS13 04/08/07 SGS/PAG ADFE RF 06/11/13 WECJJMD SET SWELL PFQR PATCH (06/03/1 PE2MT No; 2010860 04/26/07 RM ADPERF (04/16/07) API No: 50- 029-23017 -00 11/27/07 WRR/PJC WELLHEAD LOCATION SEC 11, T13N, R13E 1169' FSL & 644' FEL 06/28/08 WRR/PJC DRAWING CORRECTIONS 02/17 /11 M9/JAD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) • `' o f T � • � \ \ I % %i THE STATE Alaska Oil and Gas ®f L S Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue �FALASY'� Anchorage, Alaska 99501 -3572 Main: 907.279.1 433 Fax: 907.276.7542 Mark Sauve FE 2 6 2013 Petroleum Engineer BP Exploration (Alaska), Inc. _ 0 / P.O. Box 196612 a d 1 Anchorage, AK 99519 -6612 Re: Northstar Field, Northstar Oil Pool, NS 13 Sundry Number: 313-027 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 this2 day of January, 2013. Encl. RECEIVED STATE OF ALASKA JAN 18 20 )3 ALASKA OIL AND GAS CONSERVATION COMMISSION f / )3 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 511 v O /Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ 1, 7 3 Stimulate ❑ Alter Casing ❑ Other: Liner Patch 12 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. BP Exploration (Alaska), Inc. Development el ' Exploratory ❑ 201 -086-0 • 3. Address: Stratigraphic El Service [] 6. API Number. P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 23017 -00 -00 - 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 458A ' NSTR NS13 • 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): 12000 ' 11256 11910 11166 None None Casing Length Size MD TVD Burst Collapse Structural Conductor None None None None Surface 3182 13 -3/8" 68# L -80 16 - 3198 16 - 3177.96 5020 2260 Intermediate None None None None None None Production 10068 9 -5/8" 47# L -80 15 - 10083 15 - 9345.35 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 4-1/2" 12.6# 13Cr80 13Cr80 14 -11270 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development 0 • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil El • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ 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 Mark Sauve.@BP.Com Printed Name Mark Sauve Title PE Signature 01/4- Phone 564 -4660 Date 1/17/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3 ( 3 - 03, -- 7 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: v'- / RBDMS JAN 2 8 201. Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: / Q — 40 ! �//� APPROVED BY / Approved by: / /�� COMMISSIONER THE COMMISSION Date: ( — ZS-- 0 FRI0G3 dA0�0 Approved application is valid for 12 months from the date of approval. Submit i ,Du licate p \43 ei • • by Date: Jan 17, 2013 To: Jerry Bixby /Rob Liddelow - Well Operations Supervisor From: Mark Sauve — Northstar PE Bob Harris - Northern Solutions Wells Intervention Specialist Subject: NS13 Slickline Deployed Swell Packer Patch GSO ANSNRWOS IOR: 250 bopd Step Unit Operation 1 S Pull SSSV. Drift and tag TD for patch deployment 2 E Set KB anchor @ 11,866' MD 3 S Deploy 3.5" swell packer patch w /snap latch QCLL system. Re -set SSSV 4 F Pump 50 bbls diesel into tubing Current Status: Producer Last Test: 1/22/12: 301 BOPD, 201 BWPD, 26.5 MMSCFPD Max Inclination: 31° at 6,169' md; 6° at Perfs Max Dog Leg: 4.3° at 50' and Minimum ID: 2" SSSV @ 1997' MD 3.725" XN nipple @ 11,257' and Last TD tag: 4/17/12: 1.92" swedge & bailer tagged TD @ 11,873' MD Last Downhole Op: 4/17/12: SBHP survey. Latest H2S value: Field Produced Gas 4 ppm - Taken from HP Separator 06/11/07 BHP: 5,114 psi @ 11,100' TVDSS, 4/17/12 NS13 was completed in late 2001 and is a high GOR well from early in life. In an attempt to make this well a competitive, low GOR producer, it was squeezed and reperfed in March 2007 but the GSO failed to make a significant improvement to the producing GOR. A follow -up P -prof in July 2007 indicated the squeeze to be leaking gas in two separate places. Since that time very little intervention work has been done on NS09. This GSO attempt will be usin • se • mented swell • acker element wi h . • / latch connections that are fully slickline deployable. Objectives 1) Shut off gas production from all but the bottom -most 20' of existing perforations and significantly reduce the producing GOR from the well. 1 Slickline Drift Procedure: 1. Hold PJSMs. Monitor and record all T /I /O pressures throughout all stages of the job. 2. SI Well, MIRU slickline unit and PT wellhead Pressure Control Equipment per SOP. 3. RIH and pull SSSV from SLVN nipple @ 1997' MD. 4. POOH and MU slickline tools with 2" bailer and XN locator. 5. RIH, locate XN nipple @ 11,257' ELMD, corrected depth, tag TD and POOH. 6. MU dummy patch consisting of (3) 10' pups, (1) 3.65" OD Round Nose Guide (1) 3.65" OD Fish neck. 7. RIH with dummy patch and tag TD. Target depth is 11,880' ELMD. If TD tags shallower than target depth then contact pad engineer and discuss options for broaching or bailing. 8. Once target TD is achieved RDMO wireline unit and return NS09 to operations. E -line Anchor Set Procedure: 9. Hold PJSM. Monitor and record all T /I /O pressures throughout all stages of the job. 10. SI Well, MIRU E -line unit and PT wellhead Pressure Control Equipment per SOP. 11. RIH with 3.70" OD Baker Single Set KB tubing anchor with 2.45" ID. (will need Baker -10 setting tool) 12. Set Baker KB tubing anchor @ 11,866' ELMD. • Reference LOCI: Schlumberger GR/CCL log dated 03/31/2007 13. POOH and confirm setting tool operation. 14. RDMO E -line unit. Slickline Patch Deployment Procedure: 15. Hold PJSMs. Monitor and record all T /I /O pressures throughout all stages of the job. 16. SI Well, MIRU slickline unit and PT wellhead Pressure Control Equipment per SOP. 17. Pick up first segment of —33' 2 -7/8" base pipe with 3.5" OD swell packer wrap & QCLL snap latch system. (note: first patch segment will have 2 -7/8" XN nipple on bottom and QCLL snap latch system on top) 2 , • 18. RIH with patch assembly until first segment tags up with KB anchor @ 1331 - g r , ELMD and then release patch from running tool. 1 i ) 8 64 19. POOH and pick up second segment of —33' 2 -7/8" base pipe with 3.5" OD swell packer wrap & QCLL snap latch system. (Note: all remaining patch segments with have QCLL snap latch system on top & bottom of assembly) 20. RIH with patch assembly to liner. Engage bottom element of QCLL snap latch system to top element from previously deployed assembly then release patch from running tool. 21. POOH and pick up next segment of —33' 2 -7/8" base pipe with 3.5" OD swell packer wrap & QCLL snap latch system. 22. Repeat Step #19 and continue deploying patch segments until a total of six 33' segments have been deployed. (final top of stacked patch elements is expect to be at approximately 11,682' MD). 23. Set SSSV in SLVN nipple @ 1997' MD. 24. RDMO slickline unit. Arrange for pump truck to bullhead 50 bbls diesel into tubing within 24 hours. 25. KEEP WELL SHUT -IN FOR AT LEAST 20 DAYS BEFORE POP. Please see attachments for downhole tool specifications and packer swell time & differential pressure ratings. Contacts For questions, please call Mark Sauve at 564 -4660 (W), 748 -2865 (C), 336 -6128 (H) or Bob Harris at 564 -4080 (0), 240 -0427 (C). cc: w /a: Well File 3 • • 1R1£. AB13YG15.1AJ• 6KSl I SAFQY Wa,.1EQ1lII�A 5551! NEi LFEAD. AMINO V1 13•541" JLTBOWL 6KSr N 13 ,,CF CHROME TEG 8.1.811••• ACTIA . BAKER 10 8707 . & 2g (® 169 tsa7' At? FIE sssv MN Am *. ,.•.. , -w 3' 2383' • Ill �I FIOO FLY IM". D =1019 Oskm IC. 11299' 011Lan ND 107100' SS 1 13.351' G'9G. 6lE, Lao BTC D. 12.115• H 3140' I — A GAS LET MAFOFELS 151-15101 kD TVO DEY TYPE VLV LATCH 0 I11 FORT OA IE 85 I iinimum : 3.725" e 11257' M 1 1612 I ao IS on I Brc I J2 D 4 -1/2" XN NIPPLE I Imp OF 7- L/it I-I 4400• s.mr x T ust Icy wa. v.? I T I9- se - CSG. 470, L•80 91IRO, D. 5081 - H 111043' I Ili I 11'171!' H41 ? CDR% Pr GAUGE, D. 351 T 1120• Hai ?N83xrap, D = se 13- I e F E 11227 HrxAtJY8,02 FERIA PIQl,D.3975 I tuAr HA1?F83 me, D- 3B1'3-I 14.1 ? 1B2, 129f.IacR 11270' ' 1 112 T5112317Q� A? 1 EB1011 M,D = 3725' I .016241, D.3950' ( 1 127'{' Tx6•B10TLFRlOPf#Z, =? I IIOP OF 41? LFR H 1127t ; Maid A1/? WLEG, D. 39661 1 I 11232" I—IHAIM LOGO 0110'157 ITLFR, 285L•8661DM, O366kpf,D =8 .276 H 11M 1 11240" HTx5' BARURFGR,D = ? i121'• H5x R FORA710NSLYMRY REF LOG: L11Ultw Rodolniy 11118 •2'0 2001 AlEILE AT TOP FEFF: 4' 11858' Nor: Ridge b Roc i i IE far HAWAII pad dim SEE SPF NrWVAL(1L» CpriSgz GATE 2•77T 8 11724 • 11831 S 03 /17107 2.717 6 1104 • 11884 S GM 707 2.7IT 6 11858 • 11874 0 04/1607 2•70T 6 11869 • 11568 S 03/1 757 2•717 6 11174 •11584 0 045607 2•7YT 6 11860 • 11890 0 0/51417 I 0' 1 ' I 4.1J2 - LFEL 1186,13CR SAM -ACE 11473' ++ 1i *i * i4 � i } 1 152 bpi, 0.395B- I-1 DATE FEY BY COISENrs OAIE FEY 9Y COAN@irs NORIN LAR 425271 JAS FEEL COMPLETION 040861'7 SGSA#.G ADFHF WELL NS13 1251401 MT HOST REFORMED 04I2857 RAFIILM RENEW (01!1657) PROW lb_ 20108 ea 12/2002 9F LIOAIF)KB INFO 1112757 PARRRC riaLHOLOG11ONC SON, Ail lb: 80-029•2301 MO 115105 KIM NM FORMAT 06126.06 MRfi M ORAMIG OORECIION8 SEC 11,11 EL RI S., 1165 FSL 8 644' FEF G3J1757 JGMF AG SOR13 RE FS 02017711 IIMMI ADO® SS511 SAFETY DDTE 045107 Q1ARC PERE ISM DAM B.1 3 SP f}plorallon (Alaska} 4 . , 0 • , i 1 Schluntergor •---::..,?-. 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I , , , I _ , * 111111' 1n111n1'11mMI11 w • ilii. r�J�iliiYrr a ulc� sl IIi iL i�li�irl4 i��1L11Mi1,Ii Ill����� Iul 11111 IIIINIIIIIIIINIIIi1111NUll llnlln! INMINIMILINMEIBMIE �. I NE IIIMENU Seli!llllzullQMIIIlns -OM . 1 I 1 lI!1u1nlQ �� Ini 11111 IIIIIIIIn1111N111I11111u11 II M ' IIIMMIIHNIMM11111111 IIIIIMIMMIMININIMIAMMIUM1111111 MUM OMMEIMMIIIIIIMMIN I .: 8"- E E i■I 111111 in1n1111111111 u 11111 1luINH I i1 ININIIINI� 'Inl IN1 .111111 uIlluilll 1 1 ►11:11' i 'I!�I5/�iiIaIIihw"1 Imirdii • . ! x i ( .11 • • A ' 29,5" HES Swell (5) 'I 320x' -r X3.0' Snap Latch Assembly (5) 29.5' HES Swell (4) -- 13237.5` --- I I -3.0' Snap Latch Assembly (4) g i 13240 __...._._..._ i. 111 29 -5' HES Swell (3) 13270' — -33.4 ^'3.0' Snap Latch Assembly (3) I . � 1 3273' —i.1 I 1!. 29.5' HES Swell (2) - 13302.5'— I 1 I :1 ! -3.0' Snap Latch Assembly (2) HES Swell & Snap Latch 1 r a Running BHA — 13305.5' - b r i 28.5' HES Swell (1) .0 13335— t 1.0' 1 ....to. HES "XN" { 1 2.205 ".Vq -Vn143 , 1,65' 1.66' Snap Latch Assembly ,1) 1 I 7 • • SWELLSIM 0eawwell Swelipacker OS ',i.1111. Project Northstar Customer: BP Alaska Design By: Mike Beleau Date: 2/24/2011 Easywell Contact: Customer Contact: Bob Hans Packer Type: Swellpacker OS L 28 Area: Northstar Prudoe Bay Application: Oas/2onal Isolation Location: Well sot #13 Comments: A A Design Name; 2.878 in x 35 in x 29.528 ft Fluid Viscosity (cp): 0,736 Required DeltaP (psi): 5000 Temp at Packer Depth (°F). 250: HT application Case ID (in): 3,958 Pipe OD (In): 2.875 Packer OD (in): 3.5 Element Length (ft); 29,528 Water Cut (%): No t14.7111111P Cased Hole Design Name: 2.875 in x 3,6 in x 29.528 ft Volume Swell % at Hole ID: Time to Fully Set Max DP (days): 23.2 Time to Operational DP (days): 213 Time to First Seal (days): 9,8 Differential Pressu at Hole ID (bar): 389 Differential Pressure at Hole ID (psi): 5638 Created on 2124/2011 348:37 PM Pace 1 of 2 f 8 • • Perforation Attachment ADL0312799 Well Date Perf Code MD Top MD Base TVD Top TVD Base NS13 3/17/07 SQZ 11724 11834 10980 11090 NS13 4/16/07 SQZ 11834 11856 11090 11112 NS13 4/16/07 APF 11856 11860 11112 11116 NS13 4/16/07 APF 11860 11864 11116 11120 NS13 4/16/07 APF 11864 11866 11120 11122 NS13 4/16/07 APF _ 11866 11874 11122 11130 NS13 4/8/07 APF 11874 11876 11130 11132 NS13 4/8/07 APF 11876 11880 11132 11136 NS13 4/8/07 APF 11880 11886 11136 11142 NS13 4/8/07 APF 11886 11890 11142 11146 NS13 4/8/07 APF 11890 11894 11146 11150 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 • Casing Summary ADL0312799 Casing Length Size MD Top MD Base ND Top ND Base Burst Collapse Grade LINER 699 1 -1/2" 12.6# 13Cr8( 11276 11975 10533 11231 8430 7500 13Cr80 LINER 1568 7" 26# L -80 9920 11488 9184 10745 7240 5410 L -80 PRODUCTION 10068 9 -5/8" 47# L -80 15 10083 15 9345 6870 4760 L -80 SURFACE 3182 13 -3/8" 68# L -80 16 3198 16 3178 5020 2260 L -80 TUBING 11256 4 -1/2" 12.6# 13Cr8( 14 11270 14 10527 8430 7500 13Cr80 • • . , • • Packers and SSV's Attachment ADL0312799 Well Facility Type MD Top Description TVD Top NS13 PACKER 9900 7" Top Packer 9164 NS13 PACKER 11222 7" Top Packer 10479 NS13 PACKER 11276 5" Top Packer 10533 • TREE= ` ABB-VGI 5-1/8" 5Y NOTES: WELL REQUIRES A SSSV. V1/tLLHEAD = ABB -VGI 13 -5/8" MULTIBOWL 5 ***4 -1/2" CHROME TBG & LNR** ACTUATOR = BAKER N KB. ELEV = 56.19' BF. ELEV = 40.29' (CB 15.9') KOP = 2363' 1997' I- 4 -1/2" HES SSSV Max Angle = 31° @ 6354' I • w / HXO SLV NIP, ID = 3.813" Datum MD = 11299' Datum TV D = 10500' SS 113 -3/8" CSG, 68 #, L -80 BTC, ID = 12.415" H 3198' GAS LIFT MANDRELS ST MD TVD DEV I TYPE VLVI LATCH PORT DATE Minimum ID = 3.725" @ 11257' 1 5161 4912 30 SMOR DMY BK 0 11/28/01 4 -1/2" XN NIPPLE TOP OF 7" LNR H 9900' I J I 9900' I-19-5/8" X 7" LNR TOP PKR, ID = ? I I9 -5/8" CSG, 47 #, L -80 BTM-C, ID = 8.681" H 10083' I--'• I 11178' 1-14-1/2" CIDRA PT GAUGE, ID = 3.813" I ' I 11200' H4-1/2" HES X NIP, ID = 3.813" I 11222' 1-17" X 4-1/2" BKR PERM PKR, ID = 3.875" I • 11246' H4-1/2" HES X NIP, ID = 3.813" ' ( 11257' (11258' ELMD) I -14 -112" HES XN NIP, ID = 3.725" 4 -1/2" TBG, 12.6 #, 13CRVAM -ACE, I 11270' .0152 bpf, ID = 3.958" 11276' H7" X 5" BKR LNR TOP PKR, ID = ? I 'TOP OF4 -1/2" LNR 1-1 11276' � 11270' H4 -1/2" WLEG, ID- 3.958" I 11292' I-I ELMD TT LOGGED 04/01/07 I 17" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" H 11488' J A , 11290' H 7" X 5" BKR LNR HGR, ID = ? I /i G¢ 11299' H5- X 4-1/2" XO, ID = 3.958" I PERFORATION SUMMARY 11121-t- REF LOG: LWD- Vision Resistivity 11/18 - 20/2001 ANGLE AT TOP PERF: 4° @ 11856' Note: Refer to Production DB for historical perf data J191, tt SIZE SPF INTERVAL (MD) Opn /Sqz DATE 2 -7/8" 6 11724 - 11864 S 03/17/07 2 -7/8" 6 11834 - 11864 S 03/17/07 2 -7/8" 6 11856 - 11874 O 04/16/07 2 -7/8" 6 11859 - 11886 S 03/17/07 2 -7/8" 6 11874 - 11894 O 04/08/07 2 -7/8" 6 11880 - 11890 O 04/01/07 I I PBTD I-{ 11915' I // t ID 4 -1/2" LNR, 12.6 #, 13CRVAM -ACE, -I 11975' W•••• .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 12/02/01 JAS FINAL COMPLETION 04/08/07 SGS /PAG ADPERF WELL: NS13 12/04/01 MJF POST PERFORATING 04/26/07 RMH/TLH ADPERF (04/16/07) PERMFT No: 2010860 12/20/02 EMF UPDATED KB INFO 11/27/07 WRR/PJC WELLHD /LOCATION CORRECTION; API No: 50- 029 - 23017 -00 11/04/05 BJM NEW FORMAT 06/28/08 WRR/PJC DRAWING CORRECTIONS SEC 11, T13N, R13E, 1169' FSL & 644' FEL 03/17/07 JGM/PAG SQZ'D PERFS 02/17/11 MB /JMD ADDED SSSV SAFETY NOTE 04/04/07 GLM/PJC PERF, PBTD MOD, ELMD ! BP Exploration (Alaska) • • Ferguson, Victoria L (DOA) From: Sauve, Mark A [Mark.Sauve @bp.com] Sent: Thursday, January 24, 2013 7:45 AM To: Ferguson, Victoria L (DOA) Subject: RE: NSTR NS13(PTD 201 -086, Sundry 313 -027) Victoria, Good catch. The correct depth (and the depth noted on the tie -in log) for step #18 is 11,866' MD. Mark Sauve Northstar & Lisburne Production Engineer BP Exploration - Alaska 900 E. Benson Blvd Anchorage, AK 99519 Work Ph #: 907 - 564 -4660 Work Fax #: 907 - 564 -4440 Cell Ph #: 907 - 748 -2865 E -mail: sauvema(8)bp.com From: Ferguson, Victoria L (DOA) jmailto: victoria.ferguson@aalaska.gov1 Sent: Wednesday, January 23, 2013 10:47 AM To: Sauve, Mark A Subject: NSTR NS13(PTD 201 -086, Sundry 313 -027) Mark, Is the depth of 13318' ELMD in step 18 of your procedure correct? Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson(a�alaska.gov 1 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 April 21, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Northstar Dear Mr. Maunder, • by ~E~~~~I~E~' P~IAY ~ 5 ~Q11~ ~~ic ~.~. ~S_ ~~ Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Northstar di~nl~n1 n Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 50029232440000 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 50029230880000 0.5 na 0.5 na 1.7 4/30/2009 NS07 •'2020770 50029230810000 1.1 na 1.1 na 5.3 4/30/2009 NSOS 2020210 50029230680000 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 50029230520000 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 50029229850000 0.25 na 0.25 na 3 4/30/2009 NSii 2060360 50029233030000 0.75 na 0.75 na 5.1 5/1/2009 NS12 NS13 NS14A 2021100 2010860 2052020 50029230910000 50029230170000 50029230260100 1.2 1.7 0.9 na na na 1.2 1.7 0.9 na na na 3.2 6.8 2.8 5/1/2009 5/1/2009 5/1/2009 NS16A 2061410. 50029230960100 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 50029231130000 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 50029231020000 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 50029231220000 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 50029231180000 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 50029231260000 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 50029231280000 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 50029231460000 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 50029231110000 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 50029231810000 na na 2.6 5/2/2009 NS-26 2002110 50029229960000 at surface na na na na na NS27 2010270 50029230030000 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 50029232480000 1.5 na 1.5 na 8.1 5/3/2009 NS30 2052070 50029232930000 0 na 0 na 4.3 5/3/2009 NS32 2031580 50029231790000 na na 1.7 5/3/2009 NS33A 2081890 50029233250100 Sealed conductor na na na na NS34A 2080170 50029233010100 0 na 0 na 2.2 5/3/2009 *Not measured due to rig proximity. • • by BP Exploration (Alaska) Ina Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~ '''° ` ~~~ zq~ May 26, 2009 ~1~~ iii ~ ~97~~ ~~,~li~sion lal~r Mr. Tom Maunder Alaska Oil and Gas Conservation Commission , ~~ 333 West 7t" Avenue ~~, Anchorage, Alaska 99501 ~ 2' ~~ 1~ Subject: Corrosion Inhibitor Treatments of Northstar Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, "(,~-~ Andrea Hughes BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~~ ~~~ Date Northstar 5/26/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 1.1 na 1.1 na 5.3 4/30/2009 NS08 2020210 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 0.25 na 0.25 na 3 4/30/2009 NS11 2060360 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 1.7 na 1.7 na 6.8 5/1/2009 NS14 A 2052020 0.9 na 0.9 na 2.8 5/1/2009 NS16 2061410 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 na * na 2.6 5/2/2009 NS27 2010270 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 1.5 na 1.5 na 8.1 5/3/2009 NS30 2052070 0 na 0 na 4.3 5/3/2009 NS32 2031580 * na na 1.7 5/3/2009 NS34 2080170 0 na 0 na 2.2 5/3/2009 *Not measured due to rig proximity. L JUN 0 1 2009 e tit Date 08-14-2007 Transmittal Number:92897 1 v Z007 Gons. BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Log Top SW Name Date Contractor Run Depth Bottom Depth LOQ Type u:t~ $¢O-/1Ja NS10 07 -21-2007 SCH 1 4800 7975 WATERFLOW INJECTION ú:tc. go"3-'~~ NS32 07 -20-2007 SCH 1 3760 8075 WATERFLOW INJECTION ~()9- :;)6'7- NS19 07 -08-2007 SCH 1 13650 13955 PERFORATION RECORD f~ - 03(... NS11 07 -06-2007 SCH 1 14450 14625 PERFORATION RECORD :a&f. - ()~_ NS13 07 -14-2007 SCH 1 11 534 11 790 MEMORY PPROF .UO'" ~(~ NS24 07-15-2007 SCH 1 11774 12476 STATIC BOTTOM HOLE , ~o~ -9?3 NS22 07 -09-2007 SCH 1 12600 12850 PERFORATION RECORD - )od.-Ó81 NS08 12-23-2005 PDS 1 9006 11406 CORRELATION LOG ;)Od --a ~ NS21 07 -02-2005 PDS 1 21590 22249 DEPTH DETERMINATION c.J't:~ ~oo-l~c9 NS10 01-01-2006 PDS 1 4497 5497 CORRELATION LOG ~. tL---- Please Sign and Return one copy of this transmittal. Thank You, 5~NED AUG 1 720D7 Andy Farmer Petro technical Data Center Attn: Doug Chromanski Ignacio Herrera Howard Okland Kristin Dirks Cheryl Ploegstra MMS Murphy Exploration AOGCC DNR BPXA Petro technical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp . . Date 05-24-2007 Transmittal Number:92891 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. ~ I ~ O<ð(., ÑS-~:? ü d -,;)01- Log Top SW Name Date Contractor Run Depth Bottom Depth Loa Tvpe NS13 03-31-2007 SCH MEMORY COIL FLAG PERFORATION RECORD NS13 04-16-2007 SCH WITH GAMMA RAY JEWELRY LOG GAMMA RAY NS16 04-30-2007 SCH COLLARS PERFORATION RECORD NS12 04-17 -2007 SCH WITH GAMMA RAY NS19 04-24-2007 SCH PRODUCTION PROFILE I 3.0 l - O~" \ 00- ¡é)'":t- 08-/16 - Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center RECEIVED MAY 2. 9 Z007 Attn: Cheryl Ploegstra Doug Chromanski Ignacio Herrera Kristin Dirks Christine Mahnken pJaska 011& Gas Cons. Commission Anchorage SCANNED MAY 3 1 2007 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 tþRECEIVED MAY 0 8 Z007 . Date 05-04-2007 Transmittal Number:92888 Alaska Oil & Gas ConS. Commission Anchorage QOl-oaro tzl:. 15/6(0 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Log Top SW Name Date Contractor Run Depth Bottom Depth Log Type STATIC TEMP / PRESSURE NS07 07-23-2006 PDS SURVEY REPORT STATIC TEMP / PRESSURE NS12 07-23-2006 PDS SURVEY REPORT STATIC TEMP / PRESSURE NS16 08-20-2006 PDS SURVEY REPORT STATIC TEMP / PRESSURE NS12 02-17-2007 PDS SURVEY REPORT STATIC TEMP / PRESSURE NS09 02-19-2007 PDS SURVEY REPORT STATIC TEMP / PRESSURE NS24 02-15-2007 PDS SURVEY REPORT STATIC TEMP / PRESSURE NS06 02-18-2007 PDS SURVEY REPORT DEPTH DETERMINATION NS07 07 -23-2006 PD& o~" .. E&:, 11\\1 €, 01\ ": ~ni LOG ---- c"). v '" .. I......· DEPTH DETERMINATION NS12 07 -23-2006 PDS LOG DEPTH DETERMINATION NS16 08-20-2006 PDS LOG NS12 02-17-2007 PDS JEWELRY LOG NS09 02-19-2007 PDS JEWELRY LOG NS24 02-15-2007 PDS JEWELRY LOG NS06 02-18-2007 PDS JEWELRY LOG NS24 04-10-2007 PDS PRODUCTION PROFILE NS08 04-10-2007 PDS PRODUCTION PROFILE NS13 04-07 -2007 PDS COIL FLAG NS07 07 -13-2006 PDS JEWELRY LOG / CD ROM NS12 ûì -23-2ûû6 pas JEWELRY LOG / CD ROM DEPTH CORRELATION NS16 08-20-2006 PDS STATIC SURVEY CD ROM Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp . . Date 05-04-2007 Transmittal Number:92888 BPXA WELL DATA TRANSMITTAL JEWELRY LOG / STATIC NS12 02-17 -2007 PDS SURVEY CD ROM JEWELRY LOG / STATIC NS09 02-19-2007 PDS SURVEY CD ROM JEWELRY LOG / STATIC NS24 02-15-2007 PDS SURVEY CD ROM JEWELRY LOG / STATIC NS06 02-18-2007 PDS SURVEY CD ROM PRODUCTION PROFILE NS24 04-11-2007 PDS CD ROM PRODUCTION PROFILE NS08 04-1 0-2007 PDS CD ROM NS13 04-07-2007 PDS COIL FLAG CD ROM Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Kristin Dirks Chistine Mahnken Ignacio Herrera Doug Chromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 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: REGt:.'Vt:.u ~ . STATE OF ALASKA. . ~~P'P¡ AlAm Oil AND GAS CONSERVATION COM lo~PR 2. 6 7\)07 REPORT OF SUNDRY WELL OPE I Cons. Commission D AnchoAi~f D D Waiver D Time Extension D o Re-enter Suspended Well D 5. Permit to Drill Number: 201-0860 . Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Exploratory Service 6. API Number: 50-029-23017-00-00 ~ P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 9. Well Name and Number: 56.19 KB ( NS13 - ADLO-312799 / 11. Present Well Condition Summary: 10. Field/Pool(s): NORTHSTAR Field/ NORTHSTAR OIL Pool 8. Property Designation: Total Depth measured true vertical 12000 " feet 11255.78 I feet Plugs (measured) Junk (measured) None None Effective Depth measured 11910 ' feet true vertical 11165.96 feet Casing Length Size MD TVD Burst Collapse Surface 3154 13-3/8" 68# L-80 44 - 3198 44 - 3177.96 4930 2270 Production 10039 9-5/8" 47# L-80 44 - 10083 44 - 9345.35 6870 4760 Liner 1588 7" 26# L-80 9900 - 11488 9164.25 - 10744.73 7240 5410 Liner 699 4-1/2" 12.6# 13Cr80 11276 - 11975 10533.17 - 11230.83 8430 7500 sCANNED MAY 02 2007 Perforation depth: Measured depth: 11724 - 11894 True Vertical depth: 10980 - 11150 - - - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 40 - 11270 Packers and SSSV (type and measured depth) 4-1/2" BBE SSV 4-1/2" Camco WRDP-2 SSV 7" Top Packer 7" Baker 13Cr80 Packer 1997 1997 9900 11222 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 2554 623 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 49491 62 0 817 524 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Tubing pressure 2635 770 13. Service x Contact Carolyn Kirchner WINJ WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature Title Production Engineer Printed Name Carolyn Kirchner /L..,"------ Phone 564-4862 Date 4/26/2007 Form 10-404 Revised 04/2006 l MAV {; 2 1007 b--Þb Submit Original Only . . NS13 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 61 DIESEL 5 MEOH 96 60/40 METH 11 2% KCL 173 TOTAL . . 3/31/2007 CTU #6 ****Job Continued from 3-30-07 WSR***Continue with weekly BOP test. MU BHA #1: Weatherford 2 7/8" motor and 3.70" 5 bladed cement mill. RIH with BHA #1. Tag down at 11694' ctm. Begin milling with 2% XS KCI with 0.6% SafeLube. Mill hard cement from 11835' ctmd. At 11865', encounter drilling break. Continue cleaning out to 11890' ctmd. Pump 10 bbl FloPro sweep and chase OOH at 80% pump rate. MU logging tools. RIH with Weatherford MHA and SLB memory logging tools. *** Job Continued on 4-1- 07*** 4/1/2007 CTU #6 *** Job Continued from 3-31-07 WSR***RIH with Weatherford MHA and SLB memory logging tools. Log from 11896' ctmd to 11100' ctmd. Paint flag at 11400' ctmd. POOH. Confirm good data. Depth correction +20' (Cooreleated to RU 10' , 2.875" Power Jet 2906, HMX SLB perforating gun. RIH and correct depth at flag to top shot. RIH to perforation depth. Underbalance well by 400 psi and perforate from 11880' to 11890'. POOH. Confirm guns fired, recover 1/2" ball. Begin rigging down CTU. ***Job Continued on 4-2-07 WSR*** 4/2/2007 CTU #6*** Job Continued from 4-1-07***Continue rigging down wellhead equipment. Standby to move to next location. Move unit to NS-19. *** Job Complete*** CTU #6 ***Job Flag & Add Perf*** MIRU Preform test per Sundry. RIH w. Gama/CCL in 2.2 carrier, 3" JSN Tag bottom @ 11885' CTM, Log from 11883' @ 40 fpm stop & paint flag @ 11800', continue logging to 11400', POOH ...Continue job on 4/8/2007... 4/8/2007 CTU #6 ***Continue job from 4/7/2007*** Data retrieved from memory tools indicate +23' correction. RIH wi WF 2 3/16" MHA, CBF firing head, two 10' 2 7/8" HSD guns. Add perfs from 11,874'-11,894'. POOH displacing well wi diesel to 4000'. RDMO. *** Job complete*** 4/12/2007 ***well shut in on arrival*** ran 3.50" cent., 1 7/8" x 3' wb, 3,75" xn locator locate xn nipple @ 11,246' slm - 11,259' elmd = 13' correction ran 2.875" x 10' dummy gun & 1 1/2" sample bailer, tag td 11,886' slm + 13' correction = 11,899' md ran pds memory tools, performed sbhp as per program see pds memory log for data ***well shut in on departure*** 4/15/2007 attempted to add perf. tools failed. will continue on 04-16-07 4/16/2007 SHOT 11856.5'-11874'W/2.88" PJ IN PURE GUN CONFIGURATION. USED GRICCL TO CORRELATE TO SLB MEMORY GRICCL LOG DATED 31-MAR-07. ALL SHOTS FIRED, 411 ***Well Flowing on ariival*** TRAVEL, READY EQUIP AND TOOLS FOR AM RIG UP. CUT 5900' .125 CARBON STEEL WIRE TO GET TO GOOD WIRE! Left well continue in the AM 4/20/2007 ***W ELL AR R IV AL *** Attempt to set 4.5" BBE could not get BAL.-LINE to purge. Set 4.5" QOS WI RQ LOCK NO NO-GO RING Ser.# QOS-17 ,3 sets of packing, Cont. opperated, Bal. & Chem ports plugged. Perform state test on SSSV and surface safety equipment wi Well Tender "PASSED" ***TURN WELL OVER TO WELL TENDER, TURN IN PERMIT*** . . .. . Preble, Gary B (SAIC) From: Sent: To: Subject: Kirchner, Carolyn J Wednesday, April 25, 20074:49 PM Preble, Gary B (SAIC) NS13 Perfs Perfs were shot 3 separate times after the initial squeeze: Intervals shot: 'fll 2, 25 7:.5 11,880-11 ,890 !. 11,874-11,894"'-' 9 B V 2. 87'S i . 11,865.5-11,874 - odd numbers due to type of gun us"ea. - <it >0 Carolyn Kirchner ACT East PE BP Ine kircc i@bp.com 564-4862 7814062 (cell) \ ( ~G/ LS V\.~ , rfL fD v--[ \}t u:Á.'" D lo\ I) . ~ Sf-Ç- ~ {L ~16 \\ 0C=> ~(' ¿cCO Re: FW: CTU: NS13 Perforations Post Cement Squeeze e e Bob, You are adding to the operations previously approved. This email is sufficient. Tom Maunder, PE AOGCC Younger, Robert 0 wrote, On 4/4/2007 11 :52 AM: Tom, It appears that our initial perf strategy for NS13 was too conservative and the well is having difficulty flowing. Therefore, we would like to add and re-perforate per the attached procedure. Please let me know if this notification is sufficient to proceed or if additional information is required. Thanks! Bob From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, March 27, 20072:32 PM To: Younger, Robert 0 Subject: Re: FW: au: NS13 Cleanout Post Cement Squeeze Thanks Bob. You all know what makes the most operational sense. Hope the stars stay aligned for you. Tom Maunder, PE AOGCC SCANNED APR 0 9 2007 Younger, Robert 0 wrote, On 3/27/2007 2:24 PM: Tom, Just wanted to keep you up to date on the latest regarding the NS13 squeeze, the current plan is to perforate NS13 with coil rather than e-!ine. This will save us a couple of rig-ups. In addition, the memory GR/CCL on coil pre-perfs will help us ensure we have milled deep enough. Assuming the ice road is still in good condition following this recent blow, the coil unit could be back to Northstar around Thursday. Please let me know if you have any questions or need any additional information. Thanks! Bob From: Younger, Robert 0 Sent: Monday, March 26, 2007 6: 13 PM To: G ANC Wellwork Program; Nstar, Control Room; Nstar, Lead Tech; Nstar, Ops Team Leader; NSU, Nstar Ops Support Supv; Hobson, Max B; Helmandollar, Troy A; Nstar, DIM/Area Manager Cc: Denis, John R (ANe); Garing, John D; Nitzberg, Katie E; Martinez, Stephen A; Francis, Michael J; Nstar, Scheduler; Julian, Jennifer Y; Nstar, Maint Planner; Olsen, Clark A; Norene, Tyler M; Rochin, William R. (Orbis Engineering Inc.); Harris, Robert M; Archey, Pat; Cismoski, Doug A; ACT, Environ Advisor East; Zambrano, Abraham (Schlumberger); NSU, erc Prod Chem (Nalco); ACT, erc Ops Integrity Support Specialist; Kuzma, John H; Spano, A J; Lawler, Christy X; Broacha, Melody S; Preble, Gary B (SAIC); Deckert, Steven L; Bixby, Jerry L; Clump, Robert C; 10f3 4/4/20072:48 PM Re: FW: CTU: NS13 Perforations Post Cement Squeeze e e Sachivischik, Natalya (Schlumberger); Yeager, Kevin E Subject: FW: CTU: NS13 Cleanout Post Cement Squeeze Please plan to perforate NS13 with coil following the coil cleanout. This will eliminate a slickline and e-line rig-up. We will still need to run the SSSV. Please plan to run the SSSV and POP the well AFTER the coil unit is done with the NS12 & NS19 coil acid jobs. Coil: NS13 - Cleanout, Memory GRlCCL tie-in log, Perforate 10' Per the below PowerPoint, please note that there was a 3.51" restriction at 11,728' MD pre-sqz and post-sqz the restriction at this depth is less that 2.875". Also, the intent is to shoot 10' of perforations as deep as possible. The proposed perf interval is 11876'-11886' MD; however, if the cleanout provides additional rat hole the plan will be to perforate as deep as possible - the oil water contact is at 11,900' MD. Please let me know if there are any questions, comments or concerns. Thanks! Bob «NS13 Ad-Re Perf Procedure Post GSO SOZ UPDATE 03-26-2007.xls» «NS13 GSO SOZ Log.lIP» From: Younger, Robert 0 Sent: Tuesday, March 20, 2007 5:36 PM To: G ANC Wellwork Program; Nstar, Control Room; Nstar, Lead Tech; Nstar, Operations Manager; Nstar, Ops Team Leader; NSU, Nstar Ops Support Supv; Hobson, Max B; Helmandollar, Troy A Cc: Denis, John R (ANC); Garing, John D; Nitzberg, Katie E; Martinez, Stephen A; Francis, Michael J; Nstar, Scheduler; Julian, Jennifer Y; Nstar, Maint Planner; Olsen, Clark A; Norene, Tyler M; Rochin, William R. (Orbis Engineering Inc.); Harris, Robert M; Archey, Pat; Cismoski, Doug A; ACT, Environ Advisor East; Zambrano, Abraham (Schlumberger); NSU, erc Prod Chem (Nalco); ACT, erc Ops Integrity Support Specialist; Kuzma, John H; Spano, A J; Lawler, Christy X; Broacha, Melody S; Preble, Gary B (SAIC); Deckert, Steven L; Bixby, Jerry L; Clump, Robert C; Sachivischik, Natalya (Schlumberger) Subject: CTU: NS13 Cleanout Post Cement Squeeze Post Cement Sqz we are unable to get to TD and several tight spots have been identified by slickline. Therefore, please plan to perform a coil cleanout in order to allow for the post-sqz perforations to proceed. Slickline Tiç¡ht Spots 11,728' MD (please see caliper in attached PowerPoint - 2-7/8" Dummy Gun did not pass through) 11,740' SLMD - -11,752' MD 11,753' SLMD - -11,765' MD 11,820' SLMD - -11,832' MD 11,830' SLMD - -11,842' MD Current TD: 11,835' SLMD - -11,847' MD «NS13 Post Sqz 2007.ZIP» «NS13sundry307-012 (2).ZIP» Robert Younger 2 of3 4/4/2007 2:48 PM Re: FW: CTU: NS13 Perforations Post Cement Squeeze e e BP Exploration, Alaska Northstar/Badami Production Engineer 907-564-5392 (Work) 907-677 -2599 (Home) 907 -830-4920 (Cell) younç¡er2@bp.com 30f3 4/4/2007 2:48 PM e PERFORATING PROCEDURE e Ver 4.0 06104101 Well: NS13 Date: API #: 50·029-23017-00 .,.............."."..0 CO'V' "_"",H'.'". Prod EngrF39.~f'!r:t..'(()lJf1øf'!~. Office Ph: Home Ph: Cell: 564-5392 . ,,,....^...-......._,,...-.,,.-.,,.. 677-2599 830-4920 .............."............ CC or AFC: NSFLDWL 13 Description: ::F3~:Dii4:Þ~íis.·· Detail Code: """".'''''.''...,. .......,...........,..- ........................,..,,"^ . H'.H'.....·"..........._..· WBL Entries Type lOR DSWL AFE Job Description C 200 NS13 NSFLDWL 13 DriftfTaQ Mem GRlCC, Perforate 11874' - 11894' S 201 N513 NSFLDWL13 Run S55V Well Obiectives and LOQaina Notes: It appears that the initial perf strategy post-sqz was too conservative. Tr1erefore. please Sl100t the proposed perforation intervaL For questions or comments please cail Bob Younger at 564-5392 (w). 677-2599 (11), or 830-4920 (celi). Attachment: Reference Log Log: I\!DYì'3.i().Ilf'{i:J¡;íS Date: 11/20/2001 Company: 's'ëtìílìrïiber Depths (from-to) Tie in Log GH/CCL 4/4/2007 . s:~hi~r.Ï1Þ~r.ii~r Depths (from-to) . J.iß?4:.... .. . .11.!.ª§J.~V ... See Annotated Log for Tie-in Add/Subtract from the tie-in ¡ëi¡;ïto'be on depth with the reference log. feet Feet 20' SPF Orient. Random Phasing 60° 0 o o o o Zone Ad/Rellperf ........,...,...,...,..,...., ."................".--.... ..... . . H^....~..... ......"..'."'"'n.'.,...... .,...'"""..."............ "H "..........,.... .......................,.. """"""'.,.'..." ...".............,"... Gas Jetting Expected? No At what Depth? ................,."....... Requested Gun Size: ..?ß?0':..!j.§D Charge: Power Jet 2906, HMX Desired Penetration: Is Drawdown Necessary/Desired/Unnecessary During Perforating Entry Hole Diam: 0.38" "" e.w.">"......... ..,."'. ... "H·"""'" .."",.".....,...,............".......c.....' Describe below haw t() açhi~w drawrÞ,;v/Ti {ç!~~çk wi Paä Operatar to søe it ne(;$$SEry piping is i:1$.tfiHed} ......................"... ·,........0.".......',,·,..·........·... ,........"....................... (e.g. /If? Lift, f-!adiifi6 Lift Gas, Gas tAt, Ffow WeN. Ba,;kfiûw Ttrroaah Drain or Hardfine} ...'.,.........................."..."....... ....."............... .. ·····.......,...^.....·,,····.......n..".. Tie in to Jewelry @ Minimum ID: Tail Depth: MD 3.725 in 1..1,:,!ªª... ft MD Tie in using: Min ID Type: Casing Size: Est Res. Pres. @ ......4~~.(?::.~N::N:~p.pI~:::::::::::···,· ,·,··@'·':::~j:':?~:1::·ïÑió 4.5 in 12.6# 13-CR Liner ......................... ..!.1.!.1.Q9.... MD is 5,098 psi ..........,.....................................,.,.,... Last Tag: 1..1ß~º... ft CTMD on 3/31/2007 ",.,."..........0...0.".. Well: Date: NS13 Perforation Summary API #: 50-029-23017-00 '...,.,.......................h................'.".' , On-Site Prod Engr: PBTD General Comments: Balance O/B/U O/B/U O/B/U O/B/U O/B/U Depths Referenced to BHCS Feet SPF Orient. Phasing Zone Aperf/Reperf 00 00 o 0(.( ~BtJb ~t.i AJ je< Re: FW: CTU: NS13 Cleanout Post Cement ¡eze . Thanks Bob. You all know what makes the most operational sense. Hope the stars stay aligned for you. Tom Maunder, PE AOGCC 'dO { - O&--<o Younger, Robert 0 wrote, On 3/27/2007 2:24 PM: $CANNED MAR 2 9 Z007 Tom, Just wanted to keep you up to date on the latest regarding the NS13 squeeze, the current plan is to perforate NS13 with coil rather than e-line. This wi!! save us a couple of rig-ups. In addition, the memory GR/CCL on coil pre-perfs will help us ensure we have milled deep enough. Assuming the ice road is still in good condition following this recent blow, the coil unit could be back to Northstar around Thursday. Please let me know if you have any questions or need any additional information. Thanks! Bob From: Younger, Robert 0 Sent: Monday, March 26, 20076:13 PM To: G ANC Wellwork Program; Nstar, Control Room; Nstar, Lead Tech; Nstar, Ops Team Leader; NSU, Nstar Ops Support Supv; Hobson, Max B; Helmandollar, Troy A; Nstar, DIM/Area Manager Cc: Denis, John R (ANe); Garing, John D; Nitzberg, Katie E; Martinez, Stephen A; Francis, Michael J; Nstar, Scheduler; Julian, Jennifer Y; Nstar, Maint Planner; Olsen, Clark A; Norene, Tyler M; Rochin, William R. (Orbis Engineering Inc.); Harris, Robert M; Archey, Pat; Cismoski, Doug A; ACT, Environ Advisor East; Zambrano, Abraham (Schlumberger); NSU, CIC Prod Chem (Nalco); ACT, CIC Ops Integrity Support Specialist; Kuzma, John H; Spano, A J; Lawler, Christy X; Broacha, Melody S; Preble, Gary B (SAle); Deckert, Steven L; Bixby, Jerry L; Clump, Robert C; Sachivischik, Natalya (Schlumberger); Yeager, Kevin E Subject: FW: CTU:NS13 Cleanout Post Cement Squeeze Please plan to perforate NS13 with coil following the coil cleanout. This will eliminate a slickline and e-line rig-up. We will still need to run the SSSV. Please plan to run the SSSV and POP the well AFTER the coil unit is done with the NS12 & NS19 coil acid jobs. Coil: NS13 - Cleanout, Memory GRlCCL tie-in log, Perforate 10' Per the below PowerPoint, please note that there was a 3.51" restriction at 11,728' MD pre-sqz and post-sqz the restriction at this depth is less that 2.875". Also, the intent is to shoot 10' of perforations as deep as possible. The proposed perf interval is 11876'-11886' MD; however, if the cleanout provides additional rat hole the plan will be to perforate as deep as possible - the oil water contact is at 11,900' MD. Please let me know if there are any questions, comments or concerns. Thanks! Bob lof2 3/29/2007 9:] 4 AM Ro: FW, cru, NSI3 Cleanout Po," Cement ¡oze . «NS13 Ad-Re Perf Procedure Post GSO SQZ UPDATE 03-26-2007.xls» «NS13 GSO SQZ Log.zIP» From: Younger, Robert 0 Sent: Tuesday, March 20, 2007 5:36 PM To: G ANC Wellwork Program; Nstar, Control Room; Nstar, Lead Tech; Nstar, Operations Manager; Nstar, Ops Team Leader; NSU, Nstar Ops Support Supv; Hobson, Max B; Helmandollar, Troy A Cc: Denis, John R (ANe); Garing, John D; Nitzberg, Katie E; Martinez, Stephen A; Francis, Michael J; Nstar, Scheduler; Julian, Jennifer Y; Nstar, Maint Planner; Olsen, Clark A; Norene, Tyler M; Rochin, William R. (Orbis Engineering Inc.); Harris, Robert M; Archey, Pat; Cismoski, Doug A; ACT, Environ Advisor East; Zambrano, Abraham (Schlumberger); NSU, CIC Prod Chem (Nalco); ACT, CIC Ops Integrity Support Specialist; Kuzma, John H; Spano, A J; Lawler, Christy X; Broacha, Melody S; Preble, Gary B (SAIC); Deckert, Steven L; Bixby, Jerry L; Clump, Robert C; Sachivischik, Natalya (Schlumberger) Subject: CTU: NS13 Cleanout Post Cement Squeeze Post Cement Sqz we are unable to get to TO and several tight spots have been identified by slickline. Therefore, please plan to perform a coil cleanout in order to allow for the post-sqz perforations to proceed. slickline Tight Spots 11,728' MD (please see caliper in attached PowerPoint - 2-7/8" Dummy Gun did not pass through) 11,740' SLMD - -11,752' MD 11,753' SLMD - -11,765' MD 11,820' SLMD - -11,832' MD 11,830' SLMD - -11,842' MD Current TO: 11,835' SLMD - -11,847' MD «NS13 Post Sqz 2007.ZIP» «NS13sundry307-012 (2).zIP» Robert Younger BP Exploration, Alaska Northstar/Badami Production Engineer 907-564-5392 (Work) 907-677-2599 (Home) 907-830-4920 (Cell) younqer2(ã¿bp.com 20f2 3/29/20079:14 AM . . PERFORATING PROCEDURE Ver 4006/04101 "" RDID "___.E1S Well: Date: NS13 03-26-2007 API #: 50-029-23017-00 ............"...,.,...............<....,. Prod En!J' ..~CJ.~~~..y.().u.f.1!:!~r,....... .................................. ····.........0........... CC or AFC: NSFLDWL 13 Description: :þ.:~~(§9i.:R~:p.:~~C:::::::· Detail Code: ................,............ WBL Entries Office Ph: Home Ph: Cell: 11..··..·..·........~~t·tpe~~:··..····..··...·..¡1 564-5392 ........................... 677 -2599 ......................... 830-4920 ..,...........................................,......, TVDe lOR DSWL AFE Job Desaiption C 200 NS13 NSFLDWL 13 Cleanout Run, Drift/Tag Mem GRlCCL, Perforate 10' S 200 NS13 NSFLDWL 13 Run SSSV Post Sqœeze Ad-Re Perforation Request Well Obiectives and Loacina Notes: For questions orcommen1s please call Bob Younger at 564-5392 (w), 677-2599 (h), or 830-4920 (cell). Attachment: Reference Log IITie in Log Log: IIJD Vision Resistivity Date: "Úi20i20öT ........................ Company: ::§~b):~:~þ~f:.: :::::::::::::::::::::::::::: Depths (from-to) Depths (from-to) .....:tJ.!.ª?6..:..... .....:1..1ß.ª§.'... ....................... ......................... See Annåated Log for Tie-in Add/Subtract to the tie-in iöïjto"be on depth with the reference log. Feet 10' SPF 6 ......n................·".... ............."............. .........................n. n·....·...·,................ .n......................,.....' ............................ ............................ ............................. ...,......<..............".... ............................ ............................ ,............................ ............................... ............................ ............................ .............,....,.......... Gas Jetting Expected? No At what Depth? ............................. Requested Gun Size: ..2.ß.?.~::..t'§.P. Charge: Power Jet 2906, HMX Desired Penetration: 25.3" ...............,.......................... Is Drawdown Necessary/Desired/Umecessary During Peñorating Describe below how to achieve drawdown (check wi Pad Operator to see if necess8ty piping is installed) (e.g. N2 Lift, Hard/ine Lift Gas; Gas Lift, F/ow Well, Backflow Through Drain CY Hard/he) Tie in to Jewelry @ Minimum ID: Tail Depth: MD .........à.72ï.¡......· in ::::::::ijAªª:::::: ft MD Tie in using: Min ID Type: Casing Size: Est Res. Pres. @ Last Tag: ........~.~.!~~?..... ft SLMD on 6/3/2006 ,............................ On-Site Prod En!J': Well: Date: Perforation Summary API #: 50-029-23017-00 NS13 ------...-------_. ,...........,....,....................................,. General Comments: Balance 01 B IU 01 B IU 01 B IU O/B/U 01 B IU Depths Referenced to BHCS SP.F Orient. Feet feet Orient. Random ................,..,..... Phasing .....f3.9.~.... 0 o o o o Zone Ad/Re/lpeñ Ivishak Ad-Re Perf ..n...............·······....................·..·....................·................" ................"........ ............................................................,.,.........................., ...................."... ............,....,..............,.........,....,............,......,...................... ....,.................... '.,.....................................................................,,,.............. ......,.................. .............n..........··.............................................,,,.............,, N/A Entry Hole Diam: ..........9:.??.':........ .~.I~.!I.I>4:!..~I>.l!.~4:!..~.}.<I.r9.~t~t.ic:..p..r4:!~I>.L.':~..!~..~~.~.~..?.1.º~..!I.U.)).Qº.:.i.Il..~.r~~~........ .~~..p.~!:'<!.a.~~..IJ.f.1~.r~él:lél:f.1~~jél:..9.1è1.~.i.~.Il!..~~I>..t,l:1.a..Il.º:.~.~.~..~.i(ft..iI>..~~q.':!!.r~.L.. .º.I~.~.~.'J.III::!¡:>.!I.I>..Il.~.~.I>I>.!lry..t.>..~.Il.I>IJ..r~.!~~.~.e..U.I>..l!.1l.~rp.!I.I.a..F1.~.~.:......................... ::::::::::+~ï.?;;::~::N:ip.p.I~:::::::::..·.....·...@..·:::T(?~?::·;·MiJ..........................·........··...·...·.........· 4.5 in 12.6# 13-CR Liner :::::II;:@L:: MD is ................?Ig.~.ª. psi PBTD Phasing Zone Apeñ/Repeñ 00 00 o . ..".-"....."......,..'" ,.,...........,....--... ."."...«.,..."..,.... ...,..............-......,.,.." «..-..........--....,.... m r m ~ o m "'IlJ m--i !!II -11 Re: [Fwd: Northstar 13 Cement Sqz] . . Robert, Thanks for the notification. Conducting the additional cleanout work under the existing sundry is acceptable. As far as the new perf are concerned, you have stated all along that the desire is to shoot as deep as possible. Nothing further is needed in that regard. Good luck getting "deep". Call or message with any questions. Tom Maunder, PE AOGCC James Regg wrote, On 3/21/2007 8:33 AM: SCANNED MAR 2 1 2007 should have been sent to you -------- Original Message -------- Northstar 13 Cement Sqz Tue, 20 Mar 2007 18:16:52 -0800 Younger, Robert 0 <Robert. James Regg < im .state. .COffi> Subject: Date: From: To: .us> Jim, Following our squeeze on "NS13 we have run into a number of tight spots with slickline and are unable to get back to the planned re-perf interval. Therefore, the current plan is to re-deploy coil for a cleanout run. I assume this additional rig-up would be covered under the current sundry, but wanted to confirm. Also, the proposed perforation interval is 11876-11866' MD. Following the cleanout run we will plan to perforate as deep as possible to maximize our standoff to gas. Do we need to submit anything prior to perforating if we vary from the proposed perf interval? The perf procedure provides a proposed perf interval and states perf as close to bottom as possible. The best case is that the cleanout allows us to perforate deeper than originally planned, but there is also the risk that we will not be able to get as deep as the planned interval. Please let me know. Thanks for the help! Bob «NS13sundry307-012 (2) .ZIP» «NS13 GSO SQZ Log.ZIP» *Robert Younger* BP Exploration, Alaska Northstar/Badami Production Engineer 907-564-5392 (Work) 907-677-2599 (Home) 907-830-4920 (Cell) younger2(1)p . com 1 of 1 3/21/20078:42 AM . . fiLl CO" 0 E ...J ~ W (J) u.. tV ~ $ ,... c: ið' (f) 0 oð ~ Z CD ...J ... 0 0 25 .s (f) !fi UJ u.. .J: .r. N (f) "U t: (ñ Q.. 8 ::J 0 0 õ: OJ :z ~ z [Q ...J >. c c 0 0:1 tì a. '0 - E Qj 0 Q 8 ü: ...J Ultrasonic Imaging Tool Cement Mode 29-Nov-2001 Permanent Datum: MSL Log Measured From: RKB Drilling Measured From: RKB Elev.: K.B. 56.19 ft G.L. 15.67 ft D.F. 56.19 ft Elev.: Oft 56.19 ft above Perm. Datum 1902' FSL & 3768' FEL at surface API Serial No. 50-029-23017-00 29-Nov-2001 _.~._.___ J__._...____~__... 11998 ft 11890 ft 11890 ft 0940 ft Sectiol1i 11 Township 13N Range 13E "'''--~--,~_.---_.' --~._~-----.".~-~--'..,.".._, ~_"m·~=",.~._......·».,..".",,~......,.'ec~""" 'ne ·___",·m_"..'_·,_,~~_ a.4Ibm/ aJ 1247 T24? ~ ~'__,.~_,_.~_,~" ~w·~_·,^·_'·~ ~,~>~.~,,_~_~ 1"-"' ~" - - . r"l -- = ~ - ... § ~ ""'". .-- ----- - - ... - ... -- I-- I-- -.- .. ~. -.. - ...... ~- n .-- - - - .. --- n~ 1--- .~-,. -- -- - ..~ .. .,---- -- .- - ^",- .. 1--- ---- - n -- -- ..- - 1-- r-- - - - n_ -' - l- n -.. : II - 11600 , . , 11700 . 1 1800 f-- - - 1·- t __M I b-~----____- -~'!!D~~-- -- - - - 30õ 0 (DE'~F) c..-;:ca1orlCQ.l'lO fi_·······t~~.L-....... «...0...\' ...... .... . .., I I I I I I I I I I I I I I I I I I I . . Memory Multi...Finger Caliper Log Results Summary Company: Log Dafe: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: BP Exploration (Alaska), Inc. December 16, 2006 7121 1 4.5" 12.6 lb. 13CR VAM-ACE Tubing Well: Field: State: API No.: Top Log Intvl1.: Bot. Log IntvI1.: NS 13 Northstar Alaska 50-029-23017-00 Surface 11,866 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This log is tied into the perforations @ 11,724' (ELMD). This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damage. The caliper recordings indicate that the 4.5" tubing and liner logged are in good condition, with no significant wall penetrations or areas of cross-sectional wall loss recorded. Deposits restrict the 1.0. to 3.51" in joint 276 (11,726'). A 3-D log plot of the caliper recordings across this interval is included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. SG.'\NHE.ID fEB 1 3 2007 MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 9%) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 10%) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS: Deposits 276 @ 11,726 Ft. (MD) Minimum 1.0. = 3.51" Jt. No other significant 1.0. restrictions are recorded throughout the tubing and liner logged. RECEIVED FES 1 3 Z007 .-sOil & Gas Cons. commission Anchorage I Field Engineer: W McCrossan Analyst: M. Lawrence Witness: M. Harris ProActive Diagnostic Services! Inc. Phone: (281) or (888) 565-9085 F2D<: Prudhoe Bay Fieid Office Phone i P.O. Box 1369{ Stafford, TY 7ï497 565-1369 E-mail: PDS@rnemorylog.com 659-2307 Fax: 659-2314 ~D/ -D~~ I I I I I I Joint 275 11660 I 11610 I 11680 I Joint 276 Minimum I.D. = 3.51" 11690 I I 11700 I 11710 I 11720 I Joint 217 Perforations I (11,724' - 11730 11,864') I 11740 I I I : BP NS 3 Detail of u 3 Inc. Across Date: December 6,2006 Above Perforations 6500 MIl'll In (111000 in ) 450Q¡ I I I I I LUbricator -14 Tree Cap -13 Swab Valve -12 Flow -11 Cross -10 -9 Surface Safety Valve -8 -1 -6 -5 Master Valve -4 -3 -2 Hanger -1 0 I I I I I I I I I I I I I I u 3 n r Inc. Field: Date: Across 5-1/8" 5KSI Tree Northstar December 6, 2006 . BP NS 13 Detail of 1 I I Pipe 1 I I I I I I I I I I I I I I Correlation of Recorded Damage to Borehole Profile 4.5 in (13.4' - 11834.7') 25 50 75 100 GlM 1 125 150 (¡¡ 175 .Q E :¡ z 200 ..... .~ .2, 225 250 I Bottom of Survey = 279 I I Well: Field: Company: Country: Survey Date: NS-13 Northstar BP Exploration (Alaska), Inc. USA December 16, 2006 Approx. Tool Deviation Approx. Borehole Profile 275 279 o Damage Profile (% wall) / Tool Deviation (degrees) 50 16 1040 2115 3166 4218 5293 6343 7394 ...; w- e 8444 9491 10541 11666 11835 100 I I I Well: Field: Company: Country: NS-B Northstar BP Exploration (Alaska), Inc. USA I P S Report Ove ew ody Region alysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: December 16, 2006 MFC 40 No. 99494 2.75 40 M. Lawrence Grade & Thread 13CR V AM-ACE Nom. Upset 4.5 ins Tubing: Nom.OD 4.5 ins Weight 12.6 f I Penetration and Metal loss ('Yo wall) I penetration body metal loss body I 250 200 150 100 50 0 o to 1% 10 to 20 10 40 to over 20% 40% 85% 85% I 1 to 10% I 4 o I I Damage Configuration ( body) I I I isolated general line ring hole / poss pitting corrosion corrosion corroston íble hole I o I I Norn'!D 3.958 ins Upper len. 6.0 ins lower len. 6.0 ins Damage Profile ('Yo wall) penetration body o o metal loss body 50 100 GlM 1 = 46 i 96 - 144 ~~ ~.."' 194 .~. 244 H Bottom of Survey = 279 Analysis Overview page 2 I I I I PDS REPORT JOINT ULATION SH I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 ppf 13CR VAM-ACE 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: NS-13 Northstar BP Exploration (Alaska), Inc. USA December 16, 2006 I joint jt. Depth I'e Pen. Perr I \r\elal Min. Damag e Profile No. (Ft.) Body I.D. Comments (% wall) ( (Ins.) (Ins.) 0 50 100 .1 13 n 0.01 1 3.90 PUP , 1 16 0 0.00 1 3.92 ¡ 1.1 57 0 0.00 I 3.92 PUP 1.2 68 0 0.02 I 3.95 PUP 2 72 n 0.00 1 I 3.93 3 114 0 0.02 7' I 3.92 4 157 0 0.00 I I 3.93 5 199 0 0.00 1 I 3.93 6 241 0 0.00 J 3.94 ¡ 7 283 0 0.01 I 3.93 8 325 0 0.00 1 3.93 9 367 0 0.00 1 3.92 ¡ 10 410 0 0.00 I 3.92 11 452 0 0.01 J 3.91 12 494 0 0.00 '¡ 3.92 13 536 0 0.02 i 3.93 14 578 0 0.00 I 3.92 15 620 0 0.01 I 3.92 16 662 0 0.00 J 3.91 17 704 0.00 I I 3.93 18 746 I 0.00 3.92 19 788 I 0.01 1 3.92 20 830 I 0.00 I 3.92 21 872 11 0.00 1 3.91 22 914 0 0.00 I 3.92 23 956 0 0.01 I 3.92 24 998 0 0.01 I 3.91 25 1040 0 CWO I I 3.91 26 1082 0.00 1 3.93 27 1124 I 001 1 3.93 28 1167 I 0.01 I 3.93 29 1209 0.00 0 3.94 30 1250 0 0.01 1 3.93 31 1293 0 0.00 1 3.93 32 1335 0 0.00 n 3.93 33 1377 0 0.01 it 1 3.93 34 1419 n 0.00 II 3.94 35 1461 0 0.00 I 3.92 36 1503 0 0.01 3.93 37 1545 0 0.00 3.93 38 1587 0 0.00 3.93 39 1630 0 0.00 ¡- 3.93 40 1672 n 0.00 1 3.94 41 1714 0 0.01 2 0 3.93 42 1756 0 0.00 1 0 3.91 43 1798 0 0.00 1 I 3.93 44 1840 0 0.00 1 n 3.92 45 1882 0 0.01 7' I 3.92 46 1924 0 0.01 5 II 3.92 46.1 1966 II 0.01 2 0 3.90 PUP I I I I I I I I I I I I I Body Metal Loss Body Page 1 I I I I PDS REPORT JOINT TABULATION I I Pipe: Body Wall: Upset Wall: NominaII.D.: 4.5 in 12.6 ppf 13CR V AM-ACE 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: NS-13 Northstar BP Exploration (Alaska), Ine. USA December 16{ 2006 I Joint Jt. Depth Pel'l. Pen. ('en. ¡cAe!al Min. Damage Profile Noo (Ft.) 'I Body I.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 46.2 1976 ( 0 n n 3.81 SSSV 46.3 1979 I 0.00 n 3.92 PUP 47 1988 ( 0000 1 3.92 48 2031 ( 0.00 ¡ 3.91 49 2072 ( 0.D1 1 3.91 50 2115 ( I 0.00 1 3.92 I 51 2157 0 0.D1 2 2 52 2198 I 0.02 () i III 53 2241 ( 0.00 ~¡ 3. 54 2283 ( 0.D1 ) 3. I 55 2325 ( 0.02 1 3.90 "6 2367 ( 0.00 I 3.91 7 2409 I) 0.02 7 i 3.90 III 8 2451 0 0.00 I 3.92 59 2493 n 0.D2 3.90 III! 60 2535 n 0.02 2 3.92 III 61 2577 n 0.02 ¡ 3.91 III 62 2619 () 0.D1 ¡ 3.91 63 2661 () 0.00 1 3.90 64 2704 () 0.00 I 2 3.91 65 2745 (I 0.00 I I 3.88 66 2788 I) 0.00 I 2 3.89 67 2830 EO'OO I ¡ 3.89 68 2872 0.00 ¡ 3.89 69 2914 0.00 1 3.90 70 2956 o 0.00 ;\ 3.88 71 2998 0 0.00 I 3.89 72 3040 () 0.00 ¡ I 3.89 73 3082 I 0.00 I 2 3.88 74 3124 ( 0.01 2 3.89 75 3166 ( 0.01 2 3.89 76 3208 I 0.01 2 1 3.89 77 3250 ( 0.00 ¡ ¡ 3.90 78 3292 ( 0.D1 2 2 3.90 79 3334 ( 0.00 1 I 3.89 80 3377 () 0.00 1 ì 3.88 81 3419 () 0.D1 ;\ .3 3.89 82 3461 0 0.D1 2 2 3.90 83 3503 () 0.00 1 3.89 84 3545 0 0.00 I 3.89 85 3587 0 0.D1 ;\ 3.89 86 3629 0 0.00 1 3.90 87 3671 0 0.D1 I 5 3 3.90 88 3713 0 0.00 1 2 3.90 89 3755 (\ 0.01 ! 3.88 90 3797 ( 0.D1 I 3.89 91 3839 ( 0.01 ) 3.89 92 3881 ( 0.D1 II 3.90 93 3923 I 0.00 I 3.89 94 3965 0 0.01 ¡ 3.89 I I I I I I I I I I I I Body Metal loss Body Page 2 I I I I PDS REPORT JOINT TABULATION SHEET I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 ppf 13CR V AM-ACE 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: NS-13 Northstar BP Exploration (Alaska), Inc. USA December 16, 2006 I Joint Jt. Depth Pel Pen. Pen. /\iteial Min. Damag e Profile No. (Ft) /:::';t Body I.D. Comments (% wall) (ins.) (Ins.) 0 50 100 95 4007 1 0.00 I 3.88 96 4050 Î 0.00 i 3.90 i 97 4092 Î 0.01 ;> 3.89 W4134 Î 0.01 ¡ 3.89 4176 0 0.00 I 2 3.89 4218 ( ~ 2 3.90 4260 I ¡ 3.88 U. Deoosits. I 102 4302 1 2 3.88 I 103 4344 ( I 3.89 104 4384 ( 0.02 ) 3.88 105 4427 1 0.00 ;> 3.89 106 44{¡8 1 0.00 1 3.89 107 4509 0 0.00 1 / 3.89 108 4551 Ii 0.01 ;> I 3.89 109 4593 Ii 0.00 1 3.89 110 4635 ) 0.00 I 3.88 111 ) 0.00 I 3.90 112 4718 ) 0.01 ) 3.89 113 4760 0 0.00 2 3.89 114 4801 0 0.00 t ;> 3.89 115 4843 0 0.00 ì 2 3.89 116 4886 ¡ 0.01 2 3 3.89 117 4927 ( 0.00 1 2 3.89 118 4969 0.00 I 2 3.88 119 5011 0.00 I ¡ 3.90 120 5053 0.00 1 I 3.89 121 5095 0.00 1 J 3.90 121.1 5119 0 0 0 0 3.93 PUP OverouR (No Data) 121.2 5150 0 ( 0 N/A GLM 1 (Latch @ 1 :30) 121.3 5157 0.01 ¡ 3.93 PUP III 122 5166 i 0.00 ) 3.92 123 5208 ( 0.00 2 3.92 124 5250 ( 0.00 1 3.92 125 5293 0 0.00 3.93 126 5335 0 0.00 it 3.92 127 5377 ¡ 0.01 3.92 128 5419 1 0.00 3.91 129 5461 ¡ 0.00 3.91 130 5503 ( 0.00 3.91 131 5545 () 0.00 3.91 i 132 5587 0 0.00 I 3.91 133 5629 () 0.00 I 2 3.92 134 5671 () 0.01 2 2 3.90 135 5713 () 0.00 1 1 3.92 136 5755 0 0.00 "I 2 3.91 137 5797 0 0.00 I I 3.91 138 5839 () 0.00 1 I 3.92 139 5881 () 0.00 1 3.92 140 5923 () 0.00 I 2 3.92 141 5965 () 0.00 I I 3.93 I I I I I I I I I I I I I I Body Metal Loss Body Page 3 I PDS REPORT JOINT TABULATION I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 ppf HCR VAM-ACE 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: N5-13 Northstar BP Exploration (Alaska), Inc. USA December 16, 2006 I I I I Joint Jt. Depth Pe Pen. Pen. ¡'Aeldl Min. Damag e Profile No. UP";: Body is 1.0. Comments (% wall) (Ins.) (Ins.) 0 50 100 142 6007 n 0.01 ) ) 3.92 143 6049 n 0.01 ) 1 3.93 m1 n 001=t$ 1 3.92 145 33 n 0.00 .¡ 3.91 ¡ 1 75 0 0.01 1 3.93 1 147 6217 0 0.01 2 ) 3.93 148 6259 n 0.01 2 1 3.92 149 6301 í 000 (t 3.93 150 6343 í I 0.02 1 3.93 151 6386 0.01 3.93 152 6428 0.01 '1 3.91 153 6470 0.01 1 3.93 154 6512$ !I 0.00 I 3.93 155 6554 0 0.01 1 3.93 156 65% 0 0.01 2 1 3.94 157 6638 U 0.01 2 ) 3.92 158 6680 n 0.00 1 3.92 159 6722 n 0.01 1 3.93 160 6764 U 0.01 1 3.93 161 6806 n n.01 I 3 qL!. 162 6848 I I 0.01 I 3.93 163 6890 í 0.00 1 3.93 164 6932 U 0.00 1 3.93 165 6974 0 0.01 1 3.93 166 7016 0.01 I 3.93 167 7058 0.01 1 3.93 168 7100 0.01 I 3.q, 169 7142 I 0.00 I 3.Q' 170 7184 U 0.00 I lli~ 171 7226 0 0.01 2 I 172 7268 iJ 0.00 1 3.93 173 7310 n 0.00 2 3.93 174 7352 n 0.01 1 3.92 175 7394 n 0.01 ¡ 3.92 176 7436 U 0.02 1 3.93 177 7478 U 0.01 2 I 3.93 178 7520 0 0.01 2 I 3.92 179 7562 0 0.00 1 1 3.93 180 7604 iJ 0.01 2 ) 3.92 181 7646 iJ 0.00 1 1 3.93 182 7688 n 0.01 ì 3.93 183 7730 n 0.00 1 3.92 184 7772 n 0.00 1 3.93 185 7814 0 0.01 I 3.93 186 7856 0 0.00 1 3.93 187 7898 0 0.00 -,- 3.93 188 7940 0 0.01 ì 3.93 189 7982 0 0.00 i 3.91 190 8024 n 0.00 1 3.93 I 191 8066 C 0.00 I 3.92 I I I I I I I I I I I I I Body Metal Loss Body Page 4 I I PDS REPORT JOINT TABULATION SHEET I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 ppf 13CR V AM-ACE 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: NS-13 Northstar BP Exploration (Alaska){ Inc. USA December 16, 2006 I Joint Jt Depth PelL Pen. PeLL Ivlelal Min. Damag e Profile No. (Ft.) 'I Body In Comments (% wall) (IllS) (Ins.) (Ins.) 0 50 100 192 8108 n 0.00 2 3.92 193 8150 0 0.00 i 3.92 194 8192 n 0.01 1 3.93 195 8234 I) 0.01 I 3.93 196 I 8276 0 0.00 1 3.92 197 8318 0 0.01 I 3.93 198 8360 0 0.01 I 3.92 199 8402 0 0.01 ! 3.93 200 8444 0 0.01 I 3.93 201 8486 0 0.01 2 I 3.93 202 8528 n 0.01 ) I 3.93 203 8570 n 0.00 I 3.94 204 8612 0 0.00 1 3.92 205 8654 0 0.01 n 3.93 206 8696 0 0.01 I 3.92 207 8738 n 1IiW 3.93 208 8780 I 3.92 209 8822 0 3.93 210 8864 n 0 3.93 211 8902 n 0.011 3.93 212 8945 0 0.01 I 3.92 213 8987 0 0.00 1 -¡ 3.92 214 9029 ( 0.02 9 I 3.93 215 9071 I 0.01 3 I 3.93 216 9113 ( 0.01 1 3.93 217 9155 I 0.01 1 3.93 218 9197 I 0.01 I 3.93 219 9239 0 0.00 I 3.93 220 9281 0 0.01 0 3.94 221 9323 0 0.00 I 0 3.93 222 9365 0 0.01 2 I 3.94 223 9407 0 0.00 1 I 3.92 224 9449 I 0.00 1 0 3.92 225 9491 ( 0.00 I 3.93 226 9533 0.01 I 3.92 227 9575 I 0.00 '1 3.94 228 9617 0.01 1 3.93 229 9659 0 0.01 ) I 3.93 230 9701 0 0.00 I 0 3.93 231 9743 0 0.01 2 1 3.93 232 9785 n 0.00 I 3.93 233 9827 0 0.01 0 3.92 234 9869 0 0.01 'I 3.93 235 9911 0 0.00 Ci 3.92 236 9953 0 0.01 2 3.94 237 9995 U 0.01 2 I 3.94 238 10037 n 0.00 1 3.93 239 10079 n 0.00 1 3.93 240 10121 I' 0.01 I 3.94 241 10163 0 0.00 1 3.94 I I I I I I I I I I I I I II Body Melal Loss Body Page 5 I I PDS REPORT JOINT TABU LA TION SH I I Pipe: Body Wall: Upset Wall: Nominal I.D.: 4.5 in 12.6 ppf 13CR V AM-ACE 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: NS-13 Northstar BP Exploration (Alaska), Inc. USA December 16,2006 I Joint Jt. Depth Perl Pen. PerL Metal Min. Damage Profile No. (Ft.) Body is 1.0. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 242 10205 0 0.00 1 1 3.93 243 10247 0 0.00 I 1 3.93 244 10289 0 0.00 ¡ 3.93 245 10331 0.01 0 3.93 246 10373 0.01 1 3.93 247 1041 5 0.00 I 3.93 248 10457 0.00 (I 3.93 249 10499 0.01 (I 3.94 250 10541 0.01 (I 3.93 251 10583 ~ 4 ¡ 3.93 P 252 1 062 3 2 ! 3.92 , 253 10665 0.00 ¡ ¡ 3.92 254 10707 0.01 'I 0 3.93 255 10749 0.00 I I 3.93 256 10791 0.01 2 I 3.92 257 10833 0.01 2 0 3.93 258 10875 0 0.01 2 ¡ 3.93 259 10917 0 0.00 0 3.93 260 10959 0 0.01 ¡ 3.92 261 11001 {, 0.01 1 3.93 ,J 262 11043 (I 0.01 I 3.93 263 11085 0 g:§± 3 1 3.93 264 11125 0 1 3.93 264.1 11167 (I 0.00 I 3.92 PUP 264.2 11177 (I 0 0 3.81 PT GAUGE 264.3 11191 (I 0.00 3.92 PUP 264.4 11200 0 0 3.81 X NIPPLE 264.5 11202 (I 0.01 3.92 PUP 264.6 11212 (I 0.00 3.91 PUP 264.7 11222 0 0 (I 0 N/A PACKER 264.8 1122 5 0 0.01 2 0 3.94 PUP 264.9 11236 (I 0.01 2 0 3.93 PUP 265.1 11246 0 0 ( 0 3.81 X NIPPLE 265.2 11247 0 0.01 0 3.91 PUP 265.3 11257 0 0 0 3.73 XN NIPPLE 265.4 11259 0 0.00 I 3.91 PUP 265.6 11269 0 0 0 3.91 WLEG 265.7 11287 0 0 0 0 3.91 Too of Liner 266 11292 ( 0.00 i 3.91 1 st loint of 4.5" Liner 267 11334 I. 0.01 ¡ 3.93 268 11375 0.ü2 =i=t=t 3.92 I, 269 11415 0.01 191 270 11457 I 0.00 3.90 271 11500 0 0.01 2 1 3.91 272 11541 0 0.01 0 3.92 273 11583 I 0.01 (I 3.92 274 11624 0.01 I 3.91 - 275 11666 I. 0.01 ~tllt 276 11708 ( 0.30 100 Perforations. 277 11754 0.14 0.30 100 Perforations. I I I II II I I I I I I I I I Body Metal Loss Body Page 6 I I Pipe: Body Wall: Upset Wall: Nominal I.D.: I I Joint Jt Depth No. (Ft.) 278 11 792 279 11835 I I I I I I I I I I I I I I [I PDS REPORT JOINT TABULATION SH 4.5in 12.6ppf 13CRVAM-ACE 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: Min. I.D. (Ins.) 3.85 Perforations. 3.85 Perforations. Page 7 NS-13 Northstar BP Exploration (Alaska), Inc. USA December 16, 2006 Comments Damage Profile (%wall) o 50 100 Body Metal Loss Body .. .. .. .. .. .. Well: Field: Company: Country: Tubin : .. .. .. .. .. .. .. .. .. PDS Report Cross Sections NS-13 Northstar BP Exploration (Alaska), Inc. USA 4.5 ins 12.6 f 13CR V AM-ACE December 16{ 2006 MFC 40 No. 99494 2.75 40 M. Lawrence Cross Section for Joi Tool speed 72 Nominal 10 = 3.958 NominalOD 4.500 Remaining wall area 100 % Tool deviation = 11 0 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: 276 at depth 11725.93 ft Finger 34 Projection = -0.193 ins Deposits Minimum I.D. = 3.51 ins HIGH SIDE = UP Cross Sections page 1 .. .. .. .. I TREE = ABB-VGI5-1/8" 5 WB..LHEAD = ABB-VGI13-5/8" MJL TIBOWL 5 NS13 s. NOTES: ***4-1I2u CHROME TBG & LNR*** ACTUA TOR = KB. B..EV = 56.19' BF. B..EV = 40.29' (CB 15.9') . 1997' 1-14-1/2" SSSV w /HXO SLVN NIP, ID = 3.813" I KOP= Max Angle = 31° @ 5100 ft Me Datum MD = Datum TVD = 113-3/8" CSG, 68#, L-80 BTC, 10 = 12.415"1 3197' µ ... GAS LIFT MANDRB..S ISTI MD I TVDI DEV I TYÆ I VLV ILATCHI PORT I OATE I L 1115161149121 30 I I I I I I Minimum ID = 3.725" @ 11257' 4-1/2" XN NIPPLE 1 TOP OF 7" LNR 1 9900' 9-5/8" CSG, 47#, L-80 BTM-C, 10 = 8.681" 10083' ~ ~ 11178' 4-1/2" CIDRA Pf GAUGE, [) = 3.813" 1 I I 11200' -14-1/2" x NIP, 10 = 3.813" I "" I2S 11222' T' x 4-1/2" F'KRI ~ I I 11246' 4-1/2" X NP,ID = 3.813'" I . 11257' 1-14-1/2" XN NIP, ID = 3.725"1 4-1/2"TBG,12.6#,13CRVAM-ACE, .0152 bpf, [) = 3.958" 11269' I- ~ I 11269' 1-14-1/2" WLEG, ID - 3.958" I TOP OF 4-1/2" LNR 11276' - ~ I 1-1 EUvD TT NOT LOGGED? I T' LNR, 26#, L-80 BTC-M, .0383 bpf, ID = 6.276" 11488' -h Ii.. PERFORA TION SUMMARY REF LOG: LWo..Vision Resistivity 11/18 - 20/2001 ANGLE AT TOP PERF: 3.5 @ 11724' INITIAL PERF - CHARGE: 2906 POWffiJET, HMX ÆNETRA TION: 27", HOLE: 0.36", PHASE: 60 DEG. Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2-718" 6 11724 - 11864 0 12/01/01 2- 7/8' 6 11834 - 11864 0 01/19/05 2- 718' 6 11859-11886 0 01/20/05 ] IPBIDI 11887' I 4-1/2" LNR, 12.6#,13CRVAM-ACE, 11976' .0152 bpf, ID = 3.958" DATE REV BY COMM:NTS DATE REV BY COMWENTS NORTHSTAR 12/02101 JAS FINAL COM PLETION WB..L: NS13 12/04/01 MJF POST PERFORATING PERMIT No: ~010860 12/20/02 EMF UPDA TED KB INFO API No: 50-029-23017-00 11/04/05 BJM NEW FORMAT BP Exploration (Alaska) I I I I I I I I I I I I I I I I I I . . SARAH PALIN, GOVERNOR AI,ASIiA. OILAlWD GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Carolyn Kirchner Production Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 5CANNEDJAN 1 9 2007 Re: Northstar Field, Northstar Oil Pool, Well Name: NS13 Sundry Number: 307-012 JO\ - ~0 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/~y of January, 2007 Encl. ~~;I' Dj 'It' (7 C1?;}- -' ,..' 4/L t'(I:::CE/~C:-D krnTE OF ALASJ. 17 07 7/?Ø1 c ALA OIL AND GAS CONSERVATION COM MI. )f. /iJ,Aj 0 9 Z007 APPLICATION FOR SUNDRY APPROVAL \h~/aska OiJ & G 20 AAC 25.280 / as Cons. Cnn- . 1. Type of Request: Abandon U Suspend U Operational shutdown L J Perforate ~ Waiver U IiflCf10,~Wer U',,/ Alter casing 0 Repair w~ Plug Perforations ø Stimulate 0 Time Extension 0 GSO SQUEEZE Change approved program 0 Pull Tubing 0 'IÇ> Perforate New Pool 0 Re-enter Suspended Well 0 2, Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ø Exploratory 0 201-0860 / 3. Address: P.O, Box 196612 Stratigraphic 0 Service o 6, API Number: Anchorage, AK 99519-6612 I 50-029-23017-00-00 J 7. KB Elevation (It): 9. Well Name and Number: 56.19 KBf NS13 I 8. Property Designation: 10, Field/Pools(s): J ADLO-312799 { NORTHSTAR Field / NORTHSTAR OIL Pool 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (It): rotal Depth TVD (It~: IEffective Depth M~ (It): Effective Depth TVD (It): IPlugs (measured): IJUnk (measured): 12000 , 11255.78 11910 11165.96 None None Casing Length Size MD TVD Burst Collapse Surface 3154 13-3/8" 68# L-80 44 3198 44 3178 4930 2270 Production 10039 9-5/8" 47# L-80 44 10083 44 9345 6870 4760 Liner 1588 7" 26# L-80 .9900 11488 9164.25 10745 7240 5410 Liner 699 4-1/2" 12,6# 13Cr80 11276 11975 10533.17 11231 8430 7500 Perforation Depth MD (It): Perforation Depth TVD (It): Tubing Size: Tubing Grade: Tubing MD (ft): 11724 - 11864 10980.32 - 11120.06 4-1/2" 12.6# 13Cr80 40 - 11270 11724 - 11860 10980.32 - 11116.06 11724 - 11834 10980.32-11090.12 Packers and SSSV Type: 4-1/2" BBE SSV Packers and SSSV MD (It): 1997 4-1/2" Camco WRDP-2 SSV 1997 7" Top Packer 9900 7" Baker 13Cr80 Packer 11222 12. Attachments: DescriDtive Summary of Proposal ø 13. Well Class alter proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development ø Service 0 14. Estimated Date for 15. Well Status alter proposed work: Commencing Operations: 1/18/2007 Oil ø Gas 0 Plugged ~ 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJD WDSPL 0 Commission Representative: Prep"lft:>u uy l:>ary Preble 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Carolyn Kirchner Printed Name Carolyn Kirchner Title ACT East PE Signature (;, ,/' \ A Ii···· ¡ /.--.. Phone 564-4862 Date 1/4/2007 r "-- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: 30'7.. 0 I d.. Plug Integrity 0 BOP Test ')Zl. Mechanical Integrity Test 0 Location Clearance 0 Other: ~G~\ ~?~*\ <:...\\-e:L>'- RBDMS 8Ft JAN 1 8 2007 S"b,,,,,",,. Fom R""";"",, '-\Q '-\ 1 n (l.~, ....,...... ..J. ~ co SIONER APPROVED BY Date: /-/?-,. () 1- Approved by: THE COMMISSION ¡b(() I ~1 ,11 ssion Form 10-403 Revised 11/2004 Submit in Duplicate . . .~ ~ ~!:.~ .~ .,.~ bp Date: To: December 15, 2006 Jerry Bixby / Clark Olsen - Well Operations Supervisor From: Robert Younger / Carolyn Kirchner - Northstar Production Engineer WK:564-5392 HM:677-2599 Cell: 830-4920 WK:564-4862 HM:N/A Cell: 603-781-4062 Subject: NS13 GSO Squeeze Est. Cost Charge Code lOR: $200M NSFLDWL 13 250 Please perform a gas shut-off squeeze on NS13. This procedure includes the following steps. Type lOR DSWL AFE Job Description Priority Comments/Other S 250 NS13 NSFLDWL 13 Pull SSSV. DrifVTag TD C 250 NS13 NSFLDWL 13 Acidize, Cement squeeze S 250 NS13 NSFLDWL 13 DrifVTaQ wI Dmy Gun (md 11886') E 250 NS13 NSFLDWL 13 Perforate (11876'-11886') S 250 NS13 NSFLDWL 13 Run SSSV Production: 1,899 BOPD; 71 BWPD; 42.7 MMSCFD Max Deviation: 30.69 deg @ 6,354' MD Max Dog Leg: 4.3 deg/100' @ 50' MD Perf Deviation: 0.4 deg Min. ID: 3.725" ID, 4.5" XN Nipple @ 11,257' MD Last TD Tag: 11,862' SLM = 11,902 corr. on 06/03/2006 Last Downhole Ops:06/03/06 - Ran petredat gauges and tagged TD at 11,862' SLM Tie-in Log: LWD-Vision REsistivity 11/18 - 11/20/2001 BHP: 5083 psi @ 11,100' md 9/14/06 Background NS 13 saw steep decline in the first year and a half of production, declining from 9,000 bopd down to 1,500 bopd with a constant GOR. After scale was detected in the well, an acid job was performed in August, 2003. This job had excellent results, and post- acid job oil rates were up to 12,000 bopd. It has since experienced some decline with an increased GOR. The primary purpose of this job is to squeeze off the existing perforations, and then reperforate the bottom 10' of perfs to re-establish NS13 as a low GOR producer. C:\Documents and Settings\preblegb\Local Settings\Temporary Internet Files\OLKBC\NS13 CTU Squeeze Program 12-15-06.doc . . Northstar Specific Information/Procedures: 1. Contact Northstar prior to mobilizing equipment. · Operations Support Supervisor - Wade Srock! Lowry Brott - 670-3520 · Operations Team Leader - Michael Johns! Ken Wood - 670-3601 · Lead Tech - Troy Helmandollar ! Brad Hobson - 670-3533 · Control Room - 670-3515 · Safety - Jim Croak! Jim Short - 670-3509 · Environmental (ACS) - Hunter Ervin! Joe Serra 670-3508 2. Contact Northstar Scheduler to arrange transport to island (days only). Lori Murray! Jeff Carter - 659-1941 · All vehicles coming to and from Northstar Island must be escorted by Northstar Logistics. Contact 659-1939 or 659-1941 prior to departure for approval. 3. Conduct Authorization to Proceed (A TP) pre-job meeting prior to commencing work. The PE is responsible for administering the A TP with the help of Operations and Safety. 4. Winter gear is required for all transportation to and from the island during the winter months. 5. Items of note: · All chemicals must be cleared with Environmental. · Spill containment is required under every vehicle. · All engine driven equipment must be logged when arriving on the island and reported to Environmental. ~ ~ Northstar ATP.doc (35 KB) Primary Squeeze Target j; &,1,0 . 1{" The perforated inteNal 11,724' - 11,886' MD Program NOTE: NS13 has chrome tubing. Ensure coil has sufficient coil life and wall thickness for proposed procedure. Slickline (Pre-Sqz) 1. Drift to SSSV W/ 3.85" gage ring. Pull 4-1/2" SSE if drift ok. 2. Drift to X nipple @ 11,200'. Locate and correct to ELM. C:\Documents and Settings\preblegb\Local Settings\Temporary Internet Files\OLKBC\NS13 CTU Squeeze Program 12-15-06.doc . . 3. Tag TO wi 3" centralizer and sample bailer (Previous tag @ 11,862' SLM, 11,902' MO on 6/3/06). Correct to ELM using previous run's correction. ). Please note any restrictions due to scale buildup in the tubing or liner. Coiled Tubing (Pre-Squeeze) Please note that Northstar wells have the potential for Shut-in Tubing Pressures up to -3900 psi. Therefore, downhole checks are required on all coil tubing operations. 1. MIRU 1-3/4" CTU wi at least 12,500' of CT. 2. MU the following BHA: 2.25" CRC, 26' stingers, and a 2.5" 00 ball drop nozzle. 3. PT HL, CT, BOP's and lubricator to 4500 psi (final squeeze pressure may reach 4000 psi at surface). 4. Open up well and prepare to pump down the backside. 5. Spear wi 10 bbls of meth water, then bullhead kill the tubing with a minimum of 277 bbls of SW (1.5 times the wellbore volume to the bottom perf). 6. When WHP drops below 1500 psi, begin RIH while continuing to pump down the backside. 7. After 277 bbls away, continue pumping down the b/s at 1 bpm and dry tag TO (reduce rate to a minimum when the nozzle is across the perfs) 8. Tag TO, PUH 10', and flag pipe. PUH above all perfs. If tag is above 11,724' call Anchorage engineer. 9. Switch to pumping down the coil @ 1 bpm to ensure the nozzle is clear and prevent gas from entering the well. Begin batch mixing cement. Coiled Tubing Acid & Squeeze 1 . Pump 25 bbls of 12 % HCI with nozzle making 1 dn and 1 up pass across perfs at max rate. 2. Overdisplace acid with 75 bbls of filtered seawater Coiled Tubing Squeeze 1. Batch mix 27 bbls (22 pump-able) of LARC cement (15.8 ppg Class G wi GasBlok). Increase IA pressure to 1500 psi with triplex. Place a field mix sample of cement in UCA at 24/f F. Cement ac should include fluid loss, slurry density, slurry temperature, slurry rheology, and filter cake thickness and quality. Compare to design parameters. Place 2 samples in a hot water bath, one with 100% cement and one with 50/50 mix of cement and biozan. 2. Pump the following: · 10 bbl fresh-wtr spacer · 22 bbl LARC 15.8 ppg cement (Attachment A). (May pump all cement in batch mixer) · 40+ bbls of fresh wtr flush C:\Documents and Settings\preblegb\Local Settings\Temporary Internet Files\OLKBC\NS13 CTU Squeeze Program 12-15-06.doc . . The cement should be pumped at a high enough rate to prevent free fall (-1.5 BPM). 3. RIH to the flag as the cement reaches the nozzle. PUH at 1:1 with chokes closed to the top perf. Reciprocate near the top perf with the chokes closed until a 1000 psi pressure bump is achieved. 4. As you see the pressure increase, position the nozzle close to the top perf when the chokes are opened. Circulate 2 bbls around the nozzle and lay in the remaining cement while maintaining constant WHP. Do not build squeeze pressure until the nozzle is above the perforations at 11,724'. Keep the coil moving at all times while laying in cement. Don't lay in remaining cement until initial squeeze pressure is obtained. If the squeeze pressure does not build then pump all cement behind pipe and pump another batch of cement. Contaminate and overflush while mixing next batch of cement. 5. After all of the cement is out of the nozzle, race to safety (-11,605', assuming no cement behind pipe). 6. Attempt to build squeeze pressure in 500 psi increments every 10 minutes to a final squeeze pressure of 3500 ilP at the perfs. Last BHP was 5083 psi at 11,100'55. Hold final squeeze pressure for 1 hour. Bleed pressure back to 1000 psi ilP at the perfs to commence the contamination and cleanout. If unable to achieve final squeeze pressure, pump all cement away and contaminate any cement in the liner and over flush. Mix and pump another 25 Bbls of LARC. Monitor the lAP during the squeeze pressure ramps. 7. Drop the ball for jetting. Maintain 1000 psi L\P for the entire cleanout. Displace ball with 1.5#/bbl biozan at max rate. Pump at least 75 bbls of bio. Begin contaminating cement after the ball lands on seat at max rate. 510w pump rate to 1 bpm when across the perforated interval to prevent blowing away cement nodes. Clean out no deeper than the coil flag. 8. Displace biozan with slick KCI or filtered seawater. Make 3 down and up passes at maximum pump rate but reduce pump rate to 1 bpm when across perfs. 9. On the final up pass, lay in 5 Bbls of 10% TEA from flag. This should more than cover the perf interval. 10. POOH at 80% while reducing POOH speed through the jewelry 11. Reciprocate (1 down pass then back up @ 50%, 10' on either side) across the following: a. Pressure transducer at 11,178' b. Gas lift mandrel at 5161'. c. 555V nipple at 1997'. 12. Lay in meth water freeze protection from 3000', Trap 1000 psi L\P on the well and 51. 13. RDMO CTU and cementing equipment Slickline/E-line (Post Sqz) C:\Documents and Settings\preblegb\Local Settings\Temporary Internet Files\OLKBC\NS13 CTU Squeeze Program 12-15-06.doc . . ATTACHMENT BP CEMENT DESIGN FORM Date: August 31, 2006 Cement Type: BHST BHCT Well: NS13 Pumpable Volume Class G LARC 245°F 235°F 22 bbls Submitted By: Robert Younaer Thickening Time 5·7 hours incl. 2 hr suñace plus 3·5 hrs pump time Filter cake Target 0.75 inches Firm cake Acceptable Range 0.6-0.8 inches Firm cake Fluid Loss Target 60cc API, cc/30 min. at BHCT Acceptable Range 50·70 cc API, cc/30 min at BHCT The slurry should have no free water. MINUTES TEMPERATURE/PRESSURE 0-120 gO°F @ Atmospheric Pressure 120-1 50 Increase pressure to 5000 psi. Increase temperature to 235°. 150-180 Gradually increase pressure to 8500 psi. 180-210 Hold Temp & Press @ 235°F & 8500 psi. 210-End of Test Decrease pressure to 5000 psi and hold 5000 through-out the remainder of the test. Increase temp by 15°/hr to a BHST of 245°F (if reached) until End of Test. Results: Please submit results to Company Man. Date of Test: Service Co. Engineer: Lab Filter cake (thickness, in): Description: Soft, Mad., Firm?: Lab API Fluid Loss: Thickening Time (hrs): Slurry Density(lb/gal): C:\Documents and Settings\preblegb\Local Settings\Temporary Internet Files\OLKBC\NS13 CTU Squeeze Program 12-15-06.doc . . 1 . WOC a minimum of 72 hours. Monitor cement compressive strength in UCA. Bleed well pressure to zero for an in-flow test. 2. RU SL. Drift/tag with 2-7/8" dummy gun. Bottom perf to be shot at 11,886'. RD SL. 3. RU EL. RIH with 2-7/8" perf guns. Perf per attached perforating procedure. C:\Documents and Settings\preblegb\Local Settings\Temporary Internet Files\OLKBC\NS13 CTU Squeeze Program 12-15-06.doc e e MICROFILMED 07/25/06 DO·NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfihn _ Marker. 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 1 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 1 22050 22242 PERFORATING RECORD STEP RATE INJECTIVITY NS32 05/15/2004 SCH 0 8321 TEST WITH RST NS27 07/21/2004 SCH 0 11332 INJECTION PROFILE PERFORATION RECORD NS13 01/19/2005 SCH 1 11550 11858 WITH GAMMA RAY fiÇANNE~) tNO\f {î 220U5 ,., J/JoIll 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-l 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~ (j /-4 C)~ Co hlL..~" ) ) Date: 08-24-2005 '! Transmittal Number:92666 !J-tJ I " oéfJÞ 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 r 'Ofaq ULTRA SONIC IMAGING LOG; NS05 04-11-2005 SCH 0 14008 CEMENT BOND LOG; ---." I). -I ~ '"' RST BORAX CHANNEL . . NS24··/· 03-27 -2005 SCH 1 12200 12473 DETECTION LOG; (,./".. MEASURE DEPTH V'" ~.. b~CI( NS05 02-15-2005 SCH 200 14033 COMPOSITE LOG; , /' NS05 02-15-2005 SCH 200 14033 TVD COMPOSITE LOG; L/'" )1 - 08" PRODUCTION PROFILE. ....' NS13 ....... 10-04-2005 SCH 11 500 11888 W/DEFT AND GHOST; ~...' ~ S'"' - ~ '1 NS05 02-16-2005 SCH 179.5 14049 CD-ROM IJlttf ..-..,., ~),... ("~ NS24/ 03-27 -2005 SCH 12200 12473 CD-ROM /3/83 ,,..,,,~"" Jj I Jl!- -,,,. ~) ...6'" NS05 04-11-2005 SCH 0 14003 CD-ROM ~J;Lj) 14 /1/-- U¡ y Pleàse Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center SCANNED SEP () 1 2005 Attn: Ken Lemley MB3-6 Attn: Ester Fueg MB3-6 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 99519-6612 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 ) STATE OF ALASKA ) REC~'~E'" w.':"".." ALASKA OIL AND GAS CONSERVATION COMMISSION . Ill"i,,, REPORT OF SUNDRY WELL OPERATIONSUN 14 200S I~b,·~.·" 1~'~'£I~d 8i f: Stimulate ŒJ :t I(ßtD~ CWtilSeQ, WaiverO Ti~lét~~Þn 0 g <'" ''''':'~'''t{;::' Re-enter Suspended Well 0 Repair Well 0 Pluç PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate D 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development []] Exploratory 0 5. Permit to Drill Number: 201-0860 6. API Number 50-029-23017-00-00 P.O. Box 196612 Anchorage, Ak 99519·6612 7. KB Elevation (ft): 56.19 8. Property Designation: ADL-312799 11. Present Well Condition Summary: Stratigraphic D Service 0 9. Well Name and Number: NS13 10. Field/Pool(s): Northstar Field / Northstar Oil Pool Total Depth measured 12000 feet true vertical 11255.8 feet Effective Depth measured 11910 feet true vertical 11166.0 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse LINER 1588 7" 26# L·80 9900 . 11488 9164.3 . 10744.7 7240 5410 LINER 699 4-112" 12.6# 13Cr80 11276 - 11975 10533.2 - 11230.8 8430 7500 PRODUCTION 10039 9-5/8" 47# L-80 44 - 10083 44.0 - 9345.4 6870 4760 SURFACE 3154 13-3/8" 68# L-80 44 - 3198 44.0 - 3178.0 4930 2270 Perforation depth: Measured depth: 11724 -11834,11834 -11860,11860 -11864,11864 -11886 True vertical depth: 10980.32 - 11090.12, 11090.12 - 11116.06, 11116.06 - 11120.06, 11120.06 - 11142.01 Tubing ( size, grade, and measured depth): 4·1/2" 12.6# 13Cr80 @ 40 SGANNED JUN 1 '7 20D5 Packers & SSSV (type & measured depth): 7" Top Packer 4-112" Top Packer 7" Baker 13Cr80 Packer 4-112" Camco WRDP-2 SSV @ 9900 @ 11276 @ 11222 @ 1997 RBDMS BFl JUN 1 () 2005 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11724' ·11886' Treatment descriptions including volumes used and final pressure: 52 Bbls 12% HCL Acid with 10% L66 Scale Inhibitor @ 966 psig. Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure 69.2 60 625 930 69.6 54 625 929 13 Prior to well operation: Subsequent to operation: Oil-Bbl 7507 7304 ! 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: Oil ŒJ Gas D Development ŒJ Service 0 14. Attachments: Copies of Logs and Surveys run_ Daily Report of Well Operations _ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 305-039 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature jj C~· C.' Cl :Æ:r~ r-urrn I 0-404 kev1s~ 4f¿004 Title Production Technical Assistant OR\G\NA~hOne 564·4657 Date 6/13/05 ) ) NS13 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/29/05 ACID/SCALE INHIBITION TREATMENT; WELL FLOWING ON ARRIVAL. MIRU DS CEMENT VAN AND N2 PUMP. HOLD ATP WITH CAMP. JOB IN PROGRESS............ AWGRS CONTINUED ON 04/30/05. 04/30/05 ACID/SCALE INHIBITION TREATMENT; CONTINUED FROM 04/29/05. COMPLETE RU. PUMP TUBING PICKLE AS PER PROCEDURE; 12 BBLS 12% HCL, DISPLACE WITH 96 BBLS SW AND 63 BBLS DIESEL. FLOWBACK PICKLE VOLUME OF 171 BBLS TO WELL CLEAN UP TANK. PUMP MAIN TREATMENT: 51 BBLS OF 12% HCL ACID W/ SCALE INHIBITOR (10%) IN 3 STAGES USING N2 FOAM AS DIVERTING AGENT. OVERDISPLACE WITH 52 BBLS 2% KCL, 114 BBLS OF SW AND 63 BBLS OF DIESEL. ASK OPS FOR 4 HOUR SOAK TIME PRIOR TO POP. JOB COMPLETE.. . NOTE: NO SIGNIFICANT PRESSURE RESPONSE FROM ACID OR FOAM DIVERSION STAGES. PUMP SCHEDULE REPORTS FLUID BBLS ONLY, NO NITROGEN VOLUME IN CUM. BBLS RECORDED. FLUIDS PUMPED BBLS 6 Neat Methanal 126 Diesel 210 Sea Water 172 20/0 KCL 52 120/0 HCL Acid with L66 Scale Inhibitor 7 NH4CL 6 N2 579 TOTAL Page 1 TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI13-5/8" Multibowl 5ksi ) NS13 1 3 3/8", 68#/ft, L-80, BTC @ 3197' MD 3177' TVD ..4 4.5", 12.6#/ft, 13-Cr, Vam Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBL/FT 9-5/8" 47# L-80 BTM-C @ 10083' 6- 4.5" X NIPPLE, @ 11200' MD' 3.813" ID 4.5" X NIPPLE, @ 11246' MD 3.813" ID 4.5" XN NIPPLE, @ 11257' MD 3.725" ID 4.5" WLEG, @ 11269' MD 3.958" ID J ) E- 7", 26#/ft L-80, BTC-M @ 11488' ~ PERFORATION SUMMARY REF LOG: LWD-Vision Resistivity 11/18 - 20/2001 ANGLE AT TOP PERF: 3.5 degrees Note: Refer to Production DB for historical perf data Initial Perf - Charge: 2.875", 2906 PowerJet, HMX; Penetration: 27"; 6 spf, Hole: 0.36"; Phase: 60 deg INTERVAL, INTERVAL, MD TVD 11,724' -11,864' 10.985'-11,125' Opn/Sqz Opn DATE 12/1/2001 PBTD @ 11887' MD, 11148' TVD 41/2" Shoe @ 11976' MD TD @ 12000' MD j DATE 12/2/01 12/4/01 12/20/02 REV. BY JAS MJF EMF COMMENTS l-inal Completion Post Perforating Updated KB Information I ')KB. ELEV = 56.19' KB-BF. ELEV = 40.29' BASE FLANGE ELEV = 15.9' SSSV @ 1997' MD, wi HXO SVLN nipple - 3.813" ID ... 4.5" GLM @ 5161 'MD, 4912' TVD wi 3.833" ID l\. - 7" LINER TOP @ 9900' MD, 9169' TVD' 4.5" Cidra PT Gauge, @ 11178' MD' 10441' TVD, 3.813" ID (Sensor ELM TVD = 10444') -;;- _ 7" PACKER, 13 Cr @ 11222' MD, I 10484'TVD 'E .. ~ 4.5" LINER TOP @ +1-11276' MD 4.5",12.6#, 13Cr Vam Ace Northstar WFI I :N513 API NO:50-029-23017 BP Exploration (Alaska) bp NS13 Survey Report Schlumberger Report Date: June 2, 2005 Survey I DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska VerticaJSection Azimuth: 284.470° Field: Northstar Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Northstar PF 1 NS13 TVD Reference Datum: RTE Well: NS13 TVD Reference Elevation: 56.19 ft relative to MSL Borehole: NS13 Sea Bed I Ground Level Elevation: 15.57 ft relative to MSL UWUAPI#: 500292301700 Magnetic Declination: 26.604° Survey Name I Date: NS131 June 10,2003 Total Field Strength: 57515.441 nT o SlODS Tort I AHD I DDII ERD ratio: 95.005° 13310.86 ft 1 5.525 1 0.294 Magnetic Dip: 80.943° SCAN~EO NOV Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet· Declination Date: July 04, 2001 Location LatILong: N 702927.879, W 14841 35.854 Magnetic Declination Model: BGGM 2004 '-' Location Grid N/E YIX: N 6030941.610 ftUS, E 659831.260 ftUS North Reference: True North Grid Convergence Angle: +1.23171236° Total Corr Mag North -> True North: +26.604° Grid Scale Factor: 0.99992902 . Local Coorc;iinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure (ft) (deg) ( deg ) (ft) (ft) (ft ) (ft ) (ft) (ft) (ft ) ( deg/100 ft ) ( ftUS ) (ftUS) RTE 0.00 0.00 0.00 -56.19 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6030941.61 659831.26 N 702927.879 W 14841 35.854 First GYD GC SS 50.00 0.40 125.40 -6.19 50.00 -0.16 0.17 0.17 -0.10 0.14 0.80 6030941.51 659831.40 N 702927.878 W 14841 35.850 100.00 0.70 143.40 43.81 100.00 -0.56 0.65 0.65 -0.45 0.47 0.69 6030941.17 659831.74 N 702927.875 W 14841 35.840 150.00 1.20 145.60 93.80 149.99 -1.20 1.48 1.47 -1.12 0.94 1.00 6030940.51 659832.23 N 702927.868 W 14841 35.826 180.00 1.30 144.10 123.79 179.98 -1.69 2.13 2.12 -1.66 1.32 0.35 6030939.98 659832.62 N 702927.863 W 14841 35.815 270.00 0.40 145.80 213.78 269.97 -2.72 3.47 3.46 -2.75 2.10 1.00 6030938.91 659833.42 N 702927.852 W 14841 35.792 364.90 0.17 79.49 308.68 364.87 -3.09 3.90 3.85 -2.99 2.42 0.39 6030938.67 659833.75 N 702927.850 W 14841 35.783 456.00 0.19 54.83 399.78 455.97 -3.31 4.18 3.93 -2.88 2.68 0.09 6030938.79 659834.00 N 702927.851 W 14841 35.775 547.00 0.06 351.08 490.78 546.97 -3.39 4.36 3.92 -2.75 2.79 0.19 6030938.92 659834.11 N 702927.852 W 14841 35.772 638.00 0.05 43.86 581.78 637.97 -3.39 4.44 3.88 -2.67 2.81 0.05 6030939.00 659834.13 N 702927.853 W 14841 35.771 729.00 0.02 11.16 672.78 728.97 -3.41 4.50 3.87 -2.63 2.84 0.04 6030939.04 659834.16 N 70 29 27.854 W 14841 35.770 '",~ 820.10 0.05 340.04 763.88 820.07 -3.39 4.55 3.83 -2.58 2.83 0.04 6030939.10 659834.15 N 702927.854 W 14841 35.771 911.10 0.07 307.20 854.88 911.07 -3.31 4.65 3.74 -2.51 2.78 0.04 6030939.17 659834.09 N 702927.855 W 14841 35.772 Last GYD GC SS 1006.30 0.08 289.63 950.08 1006.27 -3.19 4.77 3.62 -2.45 2.67 0.03 6030939.22 659833.98 N 702927.855 W 14841 35.776 First MWD+SAG 1027.52 0.28 320.95 971.30 1027.49 -3.14 4.84 3.5q -2.40 2.62 1.02 6030939.26 659833.93 N 702927.856 W 14841 35.777 1124.75 0.46 351.51 1068.53 1124.72 -2.79 5.45 3.03 -1.83 2.41 0.27 6030939.83 659833.71 N 702927.861 W 14841 35.783 1218.46 0.52 10.27 1162.23 1218.42 -2.62 6.24 2.65 -1.04 2.43 0.18 6030940.62 659833.72 N 702927.869 W 14841 35.782 1316.02 0.37 12.01 1259.79 1315.98 -2.57 7.00 2.60 -0.30 2.58 0.15 6030941.37 659833.84 N 702927.876 W 14841 35.778 1411.10 0.49 23.36 1354.87 1411.06 -2.62 7.71 2.83 0.38 2.80 0.15 6030942.05 659834.05 N 702927.883 W 14841 35.772 1506.56 0.32 7.92 1450.33 1506.52 -2.65 8.38 3.17 1.01 3.00 0.21 6030942.69 659834.24 N 702927.889 W 14841 35.766 1601.85 0.32 346.05 1545.62 1601.81 -2.50 8.91 3.35 1.54 2.97 0.13 6030943.21 659834.20 N 70 29 27.895 W 14841 35.767 1696.43 0.46 4.18 1640.19 1696.38 -2.30 9.55 3.65 2.17 2.94 0.20 6030943.84 659834.15 N 702927.901 W 14841 35.768 1791.50 0.57 344.88 1735.26 1791.45 -2.00 10.39 4.14 3.01 2.84 0.21 6030944.68 659834.04 N 702927.909 W 1484135.770 SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) NS13\NS13\NS13\NS13 Generated 7/13/200511:48 AM Page 1 of 4 2ti 1- tj~Co Generated 7/13/200511 :48 AM Page 2 of 4 NS13\NS 13\NS 13\NS 13 SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure (ft ) (deg) ( deg ) (ft) (ft) (ft ) (ft) (ft ) (ft) (ft) ( deg/100 ft ) (ftUS) ( ftUS ) 1885.78 0.49 352.48 1829.54 1885.73 -1.62 11.26 4.69 3.86 2.67 0.11 6030945.53 659833.84 N 702927.917 W 14841 35.776 1982.05 0.42 348.78 1925.80 1981.99 -1.31 12.03 5.27 4.62 2.55 0.08 6030946.28 659833.71 N 702927.925 W 14841 35.779 2075.91 0.53 19.97 2019.66 2075.85 -1.20 12.79 5.97 5.36 2.63 0.29 6030947.03 659833.77 N 702927.932 W 14841 35.777 2171.96 0.29 43.28 2115.71 2171.90 -1.36 13.47 6;64 5.96 2.94 0.30 6030947.63 659834.08 N 702927.938 W 14841 35.767 2267.80 0.29 27.52 2211.55 2267.74 -1.54 13.95 7.12 6.35 3.22 0.08 6030948.02 659834.35 N 702927.942 W 14841 35.759 2362.90 1.60 281.69 2306.63 2362.82 -0.26 15.30 7.13 6.83 2.03 1.79 6030948.48 659833.15 N 702927.947 W 14841 35.794 2458.09 3.21 282.08 2401.74 2457.93 3.73 19.29 7.88 7.66 -1.87 1.69 6030949.22 659829.22 N 702927.955 W 14841 35.909 2553.84 5.54 287.53 2497.20 2553.39 11.02 26.59 13.10 9.61 -8.90 2.47 6030951.03 659822.15 N702927.974 W1484136.116 2649.80 7.94 285.48 2592.49 2648.68 22.28 37.85 23.49 12.77 -19.71 2.51 6030953.96 659811.28 N 702928.005 W 14841 36.434 2744.21 10.46 281.76 2685.68 2741.87 37.36 52.94 38.04 16.26 -34.39 2.74 6030957.13 659796.53 N 702928.039 W 14841 36.866 2838.85 13.10 282.17 2778.32 2834.51 56.66 72.26 57.01 20.27 -53.28 2.79 6030960.73 659777.56 N 702928.079 W 14841 37.422 2933.95 15.23 282.16 2870.52 2926.71 79.91 95.53 80.09 25.18 -76.03 2.24 6030965.15 659754.71 N 702928.127 W 14841 38.091 - 3029.62 17.36 283.50 2962.34 3018.53 106.74 122.37 106.84 31.16 -102.20 2.26 6030970.56 659728.42 N 702928.186 W 1484138.861 3124.94 19.10 280.65 3052.88 3109.07 136.52 152.18 136.56 37,36 -131.36 2.05 6030976.14 659699.14 N 702928.247 W 14841 39.719 3141.73 19.36 281.54 3068.73 3124.92 142.04 157.71 142.08 38.42 -136.78 2.33 6030977.08 659693.69 N 702928.257 W 14841 39.879 3218.16 19.76 281.59 3140.75 3196.94 167.60 183.30 167.61 ·43.55 -161.85 0.52 6030981.67 659668.52 N 702928.308 W 1484140.617 3313.04 21.25 281.64 3229.62 3285.81 200.79 216.53 200.79 50.25 . -194.40 1.57 6030987.66 659635.84 N 702928.374 W 1484141.575 3408.41 22.28 279.60 3318.19 3374.38 236.07 251.89 236:08 56.75 -229.16 1.34 6030993.42 659600.95 N 702928.437 W 1484142.598 3503.50 24.18 279.40 3405.56 3461.75 273.43' 289.40 273.49 62,94 -266.15 2.00 6030998.81 659563.84 N 702928.498 W 14841 43.686 3598.71 27.75 280.23 3491.15 3547.34 314.97 331.08 315.10 70;06 -307.21 3.77 6031005.05 659522.63 N 7029 28.568 W 14841 44.894 3693.83 28.37 280.94 3575.09 3631.28 359.61 375.82 359.81 78.28 -351.19 0.74 6031012.32 659478.49 N 702928.649 W 1484146.189 3789.74 28.78 283.41 3659.32 3715.51 405.44 421.69 405.68 87.96 -396.03 1.30 6031021.03 659433.46 N 702928.744 W 1484147.508 3883.58 30.25 283.03 3740.98 3797.17 451.66 467.92 ,451.90 98.53 -441.03 1.58 6031030.63 659388.25 N 702928.848 W 14841 48.832 3979.40 30.40 284.00 3823.69 3879.88 500.03 516.30 þOO.28 1p9;84 -488.07 0.53 6031040.92 659340.98 N 702928.959 W 14841 50.217 4075.35 29.98 283.31 3906.63 3962.82 548.28 564.55 548.52 121.23 -534.95 0.57 6031051.30 659293.86 N 702929.071 W 14841 51.596 4169.68 29.47 281.33 3988.55 4044.74 595.01 611.31 595.28 131.21 -580.64 1.17 6031060.30 659247.97 N 702929.170 W 1484152.941 4264.76 29.17 280.42 4071.45 4127.64 641 .48 657.87 641.82 140.00 -626.36 0.56 6031068.10 659202.08 N 702929.256 W 14841 54.286 4360.21 28.97 281.55 4154.87 4211.06 687.77 704.25 688.18 148.83 -671.89 0.61 6031075.96 659156.37 N 70 29 29.343 W 14841 55.626 4454.99 29.82 280.14 4237.45 4293.64 734.19 750.77 '734.68 157.58 -717.58 1.16 6031083.72 659110.51 N 702929.429 W 14841 56.971 - 4550.17 29.43 283.15 4320.19 4376.38 781.17 797.81 781.71 167.07 -763.65 1.62 6031092.21 659064.25 N 702929.522 W 14841 58.326 4645.02 28.88 282.71 4403.02 4459.21 827.36 844.02 827.91 177.41 -808.68 0.62 6031101.58 659019.01 N 702929.624 W 14841 59.652 4740.12 29.09 284.20 4486.21 4542.40 873.43 890.10 873.99 188.13 -853.50 0.79 6031111.34 658973.98 N 702929.729 W 148420.971 4836.66 29.28 286.39 4570.50 4626.69 920.50 937.17 921.00 200.55 -898.90 1.12 6031122.78 658928.32 N 70 29 29.851 W 148422.307 4931.66 28.57 285.77 4653.65 4709.84 966.43 983.12 966.86 213.28 -943.05 0.81 6031134.55 658883.91 N 702929.976 W 148423.606 5026.46 29.06 287.44 4736.71 4792.90 1012.08 1028.81 1012.45 226.34 -986.83 0.99 6031146.67 658839.87 N 702930.105 W 148424.894 5121.79 29.50 286.67 4819.86 4876.05 1058.66 1075.43 1058.96 240.01 -1031.40 0.61 6031159.38 658795.01 N 70 29 30.239 W 148 42 6.206 5216.06 30.29 287.04 4901.59 4957.78 1105.60 1122.41 1105.85 253.64 -1076.37 0.86 6031172.03 658749.77 N 70 29 30.373 W 148427.529 5311.34 30.62 287.44 4983.72 5039.91 1153.84 1170.71 1154.03 267.95 -1122.49 0.41 6031185.35 658703.35 N 702930.514 W 148428.887 5406.83 30.04 286.78 5066.14 5122.33 1202.01 1218.93 1202.15 282.14 -1168.58 0.70 6031198.55 658656.97 N 702930.653 W 1484210.243 5501.26 29.66 285.14 5148.05 5204.24 1248.99 1265.93 1249.11 295.07 -1213.76 0.95 6031210.50 658611.53 N 702930.780 W 14842 11.573 5597.29 29.14 286.02 5231.71 5287.90 1296.12 1313.07 1296.23 307.72 -1259.17 0.70 6031222.18 658565.86 N 702930.905 W 1484212.909 -,. Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure· NS EW DLS Northing Easting Latitude Longitude Depth Section Departure (ft ) (deg) ( deg ) (ft) (ft) (ft) (ft) (ft) (ft ) (ft) ( deg/1oo ft ) ( ftUS ) ( ftUS ) 5692.77 28.63 285.56 5315.31 5371.50 1342.23 1359.19 1342.32 320.28 -1303.55 0.58 6031233.77 658521.22 N 702931.028 W 14842 14.215 5788.22 29.51 287.32 5398.74 5454.93 1388.57 1405.56 1388.64 333.41 -1348.02 1.29 6031245.94 658476.48 N 702931.157 W 1484215.524 5882.64 29.72 289.30 5480.83 5537.02 1435.12 1452.22 1435.16 348.07 -1392.31 1.06 6031259.65 658431.89 N 702931.301 W 1484216.828 5978.19 28.95 287.66 5564.12 5620.31 1481.81 1499.03 1481.83 362.91 -1436.70 1.16 6031273.53 658387.19 N 702931.447 W 1484218.134 6073.78 29.86 286.78 5647.40 5703.59 1528.69 1545.96 1528.70 376.80 -1481.53 1.05 6031286.45 658342.08 N 7029 31ß84 W 1484219.453 6167.71 29.92 287.09 5728.83 5785.02 1575.46 1592.77 1575.46 390.44 -1526.31 0.18 6031299.12 658297.02 N702931.718 W1484220.771 6262.67 30.52 285.56 5810.89 5867.08 1623.22 1640.56 1623.22 403.86 -1572.18 1.03 6031311.56 658250.88 N 702931.850 W 1484222.121 6354.23 30.69 284.36 5889.70 5945.89 1669.83 1687.17 1669.83 415.90 -1617.21 0.69 6031322.62 658205.60 N 702931.968 W 1484223.446 6382.86 30.56 284.54 5914.33 5970.52 1684.42 1701.76 1684.42 419.54 -1631.34 0.56 6031325.95 658191.40 N 702932.004 W 1484223.862 6479.04 30.00 284.37 5997.39 6053.58 1732.91 1750.25, 1732.91 431.64 -1678.30 0.59 6031337.05 658144.20 N 702932.123 W 1484225.244 6572.72 29.61 284.39 6078.68 6134.87 1779.48 1796.82 1779.48 443.21 -1723.40 0.42 6031347.64 658098.86 N 702932.236 W 1484226.572 '-..-- 6666.00 29.05 284.63 6160.00 6216.19 1825.17 1842.51 1825.17 454.65 -1767.64 0.61 6031358.13 658054.39 N 702932.349 W 1484227.873 6761.07 29.47 283.74 6242.94 6299.13 1871.63 1888.98 1871.64 466.04 -1812.69 0.64 6031368.54 658009.11 N 702932.461 W 1484229.199 6858.55 29.60 283.37 6327.75 6383.94 1919.68 1937.03 1919.68 477.30 -1859.40 0.23 6031378.80 657962.17 N 702932.571 W 1484230.574 6952.49 29.78 283.55 6409.36 6465.55 1966.20 1983.56 1966.21 488.13 -1904.65 0.21 6031388.65 657916.70 N 7029 32.678 W 14842 31.906 7048.51 29.58 282.13 6492.79 6548.98 2013.73 2031.10 2013.73 498.70 -1951.00 0.76 6031398.22 657870.13 N 702932.781 W 1484233.270 7142.56 29.27 281.73 6574.70 6630.89 2059.89 2077.31 2059.90 508.25 -1996.21 0.39 6031406.80 657824.73 N 702932.875 W 1484234.600 7238.62 28.72 282.09 6658.72 6714.91 2106.40 2123.87 2106.42 517.86 -2041.77 0.60 6031415.42 657778.98 N 702932.970 W 1484235.941 7333.53 28.86 281.33 6741.90 6798.09 2152.06 2169.58 2152.08 527.13 -2086.53 0.41 6031423.74 657734.04 N 70 29 33.061 W 1484237.259 7428.93 28.74 281.22 6825.50 6881.69 2197.95 2215.54 2197.99 536.12 -2131.60 0.14 6031431.75 657688.78 N 702933.149 W 1484238.585 7522.83 28.95 281.68 6907.75 6963.94 2243.18 2260.84 2243.24 545.11 -2176.00 0.33 6031439.79 657644.20 N 7029 33.237 W 14842 39.892 7617.45 28.83 281.59 6990.60 7046.79 2288.84 2306.55 2288.91 554.33 -2220.77 0.13 6031448.04 657599.25 N 702933.328 W 1484241.210 7712.87 28.29 281.00 7074.40 7130.59 2334.39 2352.17 2334.48 563.27 -2265.51 0.64 6031456.01 657554.33 N 7029 33.416 W 1484242.526 7808.90 28.13 281.35 7159.03 7215.22 2379.71 2397.56 2379.82 572.07 -2310.04 0.24 6031463.85 657509.63 N 7029 33.502 W 1484243.837 7904.60 28.12 281.61 7243.43 7299.62 2424.76 2442.68 2424.89 581.04 -2354.25 0.13 6031471.88 657465.24 N 702933.590 W 1484245.138 8000.31 27.43 281.83 7328.11 7384.30 2469.31 2487.28 2469.46 590.10 -2397.92 0.73 6031479.99 657421.38 N 702933.679 W148 42 46.423 8095.56 26.79 281.50 7412.89 7469.08 2512.66 2530.68 2512.84 598.88 -2440.43 0.69 6031487.85 657378.70 N 702933.765 W 1484247.674 8190.72 26.08 282.01 7498.10 7554.29 2554.98 2573.05 2555.18 607.51 -2481.91 0.78 6031495.59 657337.05 N 7029 33.850 W 1484248.895 8285.60 25.25 282.00 7583.62 7639.81 2596.03 2614.14 2596.25 616.06 -2522.10 0.87 6031503.27 657296.69 N 7029 33.934 W 14842 50.078 -- 8381.32 24.48 282.55 7670.47 7726.66 2636.25 2654.39 2636.48 624.61 -2561.43 0.84 6031510.97 657257.19 N 702934.018 W 14842 51.235 8476.90 23.50 282.27 7757.79 7813.98 2675.08 2693.25 2675.33 632.96 -2599.38 1.03 6031518.51 657219.07 N 702934.100 W 1484252.352 8573.45 22.64 282.84 7846.62 7902.81 2712.90 2731.08 2713.16 641.18 -2636.31 0.92 6031525.93 657181.97 N 702934.181 W 1484253.439 8668.68 22.35 283.08 7934.60 7990.79 2749.32 2767.51 2749.59 649.36 -2671.82 0.32 6031533.34 657146.30 N 7029 34.261 W 14842 54.484 8763.27 21.88 282.86 8022.23 8078.42 2784.92 2803.12 2.785.20 657.35 -2706.52 0.50 6031540.58 657111.44 N 7029 34.339 W 14842 55.506 8858.37 20.96 283.63 8110.76 8166.95 2819.64 2837.85 2.819.93 665.30 -2740.32 1.01 6031547.81 657077.47 N 702934.417 W 1484256.501 8953.94 20.36 284.13 8200.19 8256.38 2853.35 2871.57 2853.65 673.39 -2773.06 0.65 6031555.19 657044.57 N 702934.497 W 1484257.464 9049.04 20.15 283.85 8289.41 8345.60 2886.28 2904.50 2886.57 681.35 -2805.00 0.24 6031562.46 657012.46 N 702.934.575 W 1484258.404 9144.69 19.76 285.58 8379.32 8435.51 2918.92 2937.14 2919.20 689.63 -2.836.58 0.74 6031570.06 656980.72 N 702934.656 W 1484259.334 9239.37 19.50 285.55 8468.49 8524.68 2950.72 2968.94 2950.99 698.17 -2867.22 0.27 6031577.94 656949.91 N 702934.740 W 148430.235 9335.01 18.35 284.15 8558.96 8615.15 2981.73 2999.96 2982.00 706.13 -2897.19 1.29 6031585.25 656919.77 N 702.934.818 W 148431.118 9430.26 16.03 283.04 8649.95 8706.14 3009.88 3028.11 3010.15 712.76 -2924.55 2.46 6031591.29 656892.28 N 70 29 34.884 W 148431.923 SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) NS 13\NS 13\NS 13\NS 13 Generated 7/13/2005 11:48 AM Page 3 of 4 Generated 7/13/200511 :48 AM Page 4 of 4 NS13\NS13\NS13\NS13 SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ( ft) (deg) (deg) (ft) (ft) (ft ) (ft) (ft ) (ft ) (ft ) ( deg/100 ft ) ( ftUS ) ( ftUS ) 9525.44 14.62 282.82 8741.74 8797.93 3035.02 3053.26 3035.30 718.39 -2949.06 1.48 6031596.40 656867.65 N 70 29 34.939 W 148432.644 9620.58 13.14 281.02 8834.10 8890.29 3057.82 3076.08 3058.11 723.12 -2971.39 1.62 6031600.65 656845.23 N 70 29 34.985 W 148433.302 9715.10 11.83 281.84 8926.39 8982.58 3078.22 3096.52 3078.53 727.17 -2991.42 1.40 6031604.26 656825.12 N 702935.025 W 14843 3.891 9810.97 10.60 281.50 9020.42 9076.61 3096.85 3115.16 3097.16 730.94 -3009.68 1.28 6031607.64 656806.79 N 70 29 35.062 W 148434.428 9905.24 9.65 282.33 9113.23 9169.42 3113.40 3131.74 3113.73 734.36 -3025.89 1.02 6031610.70 656790.50 N 70 29 35.096 W 148434.906 9999.90 7.74 283.42 9206.79 9262.98 3127.71 3146.04 3128.04 737.53 -3039.85 2.03 6031613.58 656776.49 N 702935.127 W 148435.316 10016.77 7.72 284.06 9223.51 9279.70 3129.97 3148.31 3130.30 738.07 -3042.05 0.52 6031614.07 656774.27 N 702935.132 W 148435.381 10150.48 7.32 286.37 9356.07 9412.26 3147.47 3165.81 3147.79 742.65 -3058.93 0.37 6031618.29 656757.29 N 702935.177 W 148435.878 10244.93 6.52 285.12 9449.83 9506.02 3158.84 3177.19 3159.17 745.75 -3069.88 0.86 6031621.14 656746.28 N 70 29 35.207 W 148436.201 10339.76 5.94 280.87 9544.10 9600.29 3169.13 3187.48 3169.45 748.08 -3079.90 0.78 6031623.26 656736.22 N 70 29 35.230 W 148436.495 10434.55 5.74 287.41 9638.40 9694.59 3178.75 3197.11 3179.08 750.42 -3089.24 0.73 6031625.40 656726.83 N 70 29 35.253 W 148436.770 '- 10530.20 5.46 287.41 9733.59 9789.78 3188.08 3206.44 3188.39 753.21 -3098.15 0.29 6031628.00 656717.87 N 702935.281 W 148437.032 10624.93 5.27 288.02 9827.91 9884.10 3196.92 3215.30 3197.23 755.91 -3106.58 0.21 6031630.51 656709.37 N 70 29 35.307 W 148437.281 10719.93 4.93 285.19 9922.53 9978.72 3205.36 3223.74 3205.66 758.33 -3114.67 0.45 6031632.76 656701.24 N 702935.331 W 148437.519 10814.37 4.77 290.86 10016.63 10072.82 3213.32 3231 .72 3213.61 760.79 -3122.26 0.53 6031635.06 656693.60 N 70 29 35.355 W 148437.742 10909.06 4.35 293.37 10111.02 10167.21 3220.78 3239.25 3221.06 763.61 -3129.23 0.49 6031637.73 656686.56 N 70 29 35.383 W 148437.947 11005.44 4.24 301.83 10207.14 10263.33 3227.79 3246.45 3228.05 766.94 -3135.62 0.67 6031640.92 656680.11 N 702935.416 W 148438.135 11101.13 4.28 312.13 10302.56 10358.75 3234.33 3253.54 3234.55 771.20 -3141.27 0.80 6031645.06 656674.37 N 70 29 35.457 W 148 43 8.302 11195.17 4.08 316.72 10396.35 10452.54 3240.26 3260.39 3240.45 775.99 -3146.17 0.41 6031649.74 656669.37 N 70 29 35.505 W 148 43 8.446 11289.54 3.87 320.39 10490.50 10546.69 3245.68 3266.93 3245.83 780.89 -3150.50 0.35 6031654.55 656664.94 N 70 29 35.553 W 148438.573 11385.30 3.76 326.12 10586.04 10642.23 3250.65 3273.30 3250.76 785.99 -3154.31 0.41 6031659.56 656661.02 N 70 29 35.603 W 148438.686 11420.14 3.59 324.63 10620.81 10677.00 3252.33 3275.53 3252.43 787.82 -3155.58 0.56 6031661.37 656659.71 N 702935.621 W 148438.723 11515.93 3.48 326.59 10716.42 10772.61 3256.78 3281 .44 3256.85 792.70 -3158.91 0.17 6031666.17 656656.27 N 70 29 35.669 W 148438.821 11603.90 3.23 328.90 10804.24 10860.43 3260.53 3286.59 3260.58 797·95 -3161.66 0.32 6031670.46 656653.43 N 702935.712 W 148438.902 11708.34 3.43 335.10 10908.50 10964.69 3264.6;1 3292.65 3264.64 802.40 -3164.50 0.39 6031675.75 656650.48 N 70 29 35.764 W 148438.986 11802.31 3.61 335.32 11002.29 11058.48 3268.27 3298.42 3268.28 807.64 -3166.92 0.19 6031680.93 656647.95 N 702935.816 W 148439.057 11897.37 3.64 336.06 11097.17 11153.36 3272.0~ 3304.43 3272.03 813.12 -3169.39 0.06 6031686.36 656645.35 N 70 29 35.870 W 148439.130 Lp-¿ Pv1WD+SAG 11920.78 3.59 325.21 11120.53 11176.72 3273.05 3305.90 3273.05 814-40 -3170.11 2.93 6031687.62 656644.61 N 70 29 35.882 W 148439.151 rojected ) 12000.00 3.59 325.21 11199.59 11255.78 3276.81, 3310.86 3276.81 818.47 -3172.94 0.00 6031691.63 656641.69 N 70 29 35.922 W 148439.234 "'- Survey Type: Definitive Survey NOTES: GYD GC SS - ( Gyrodata - gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD + SAG - ( MWD + Sag correction -- MWD with a BHA deformation correction applied. Covers all BHA corrections-from simple 2D to finite-element 3D models. ) Le~al Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface: 1169 FSL 644 FEL S11 T13N R13E UM 6030941.61 659831.26 BHL: 1986 FSL 3816 FEL S11 T13N R13E UM 6031691.63 656641.69 '~' ':-', ~,' ;:.1, ~' '\ ~," :-,','E',::I t \u t I ,i \ it ( ~ If rH', 1,1 Ii ,. l: ¡ U \ ~ i: !' . I 'Ui 'j U 1'. ) t (1! ~f: IÆŒ> 'f: ¡ ~iß~\ (~lrY~',7 ,1/A'1:" ! Ii: ¡ i I, . ' , ! I: , ': o)\'~ I j~I' ' I,]J 1, lVi' " UI"\ÛI~U\ it"'. " . (: \ ~..::::J I: ,I ....:--" ", L!1 L ) ~tJ 1-- ð <¡ 0 AlfASKA OIL AlWD GAS CONSERVATION COMMISSION / I / / 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 Re: Northstar NS13 Sundry Number: 305-039 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 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 fa~ls 0 ,'Oliday or weekend. A person may not appeal a Commission decision to Superi COlrt unless rehearing has been requested. .- (Îin!t y, ,-I Jo ~. NJrlnan h~ DATED thiS~ day of February, 2005 Encl. SCANNED MAR {) 2 2DD5 bp ) ) ... ,\I,.,,,. ..'~ ~~. ~~: f~. ~'\. ¡1'''~), 'ì"""'f'"':~\"'~:~' ,. BP Exì¡ð~Jtiô.rl~b'i t¡s~' I ¡it",l n é~t.l:!::'\¡t . ~ g",.'f.¡@I 900 East Benson Boulevard ." P. o. Boxl+~B21 §l ZOO~ Anchorage, Alasiå '199519-6'&12 :ltt,~:~r~~~~1jP~~ 1r:~ ;:1:,:; February 16, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS13 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS13 well. This well has exhibited a high rate of decline and analysis of formation water indicates the /~ formation of CaC03 scale is likely. This well has responded very well to similar treatments in the past. The procedure includes the following major steps: . Bullhead HCI based acid treatment (which includes scale inhibitor) Ii . Flowback Sincerely, ~¿AJ L ;¡;. ~~ MicHael J. Fr(n~, ~p .E. Senior Petroleum Engineer BPXA, ACT, Northstar l' """" i (..." , r F l ," § . Ii i, .: I" ! c^"~ ~! l .f , ') STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALFEB 18 2005 20 AAC 25.280 \¡J61t- 2-/2 ~ I ZOOS li":~ ,£?1=~;: ,,~J ..,~~~ b:'" \~(:~, \r~;;:I,~.:~:~ \'~("""''Ië:'J:~' tij..',¡:.;..; ~ ~I;1 "~~¡,,;~ '1~:'!F"""1~~ :(; v', :"".\l',:' 1. Type of Request: 11. Presen1 Total Depth MD (ft): 12000 Casing Total Depth TVD (ft): 11260.9 Operation Shutdown D Plug Perforations D Perforate New Pool D / Development ]] Exploratory D StratigraphicD Service D 9. Well Name and Numb~F: NS13 /' 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11910 11114.9 MD TVD 4. Current Well Class: PerforateD WJivêriE:l':'I:!,::~~ StimulateOO Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 201-0860 /'/ .. / 6. API Number /' 50-029-23017-00-00 Other 0 Abandon D Suspend D Alter Casing D Repair Well D Change Approved Program D Pull Tubing D 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.19 KB 8. Property Designation: ADL-312799 Length Size Plugs (md): Junk (md): None None Burst Collapse LINER LINER PRODUCTION SURFACE Perforation Depth MD (ft): 11724 - 11834 11834 - 11859 11859 - 11864 11864 - 11885 Packers and SSSV Type: 7" Top Packer 4-1/2" Top Packer 4-112" BBE SSV 12. Attachments: 1588 699 10039 3154 7" 26# L-80 4-1/2" 12.6# 13Cr80 9-5/8" 47# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 10985.41 - 11095.2 11095.2 - 11120.2 11120.15 - 11125.1 11125.14 - 11146.1 top 9900 11276 44 44 bottom top bottom 11488 9169.3 10749.8 4930 2270 11975 10538.3 11235.9 6870 4760 10083 44.0 9350.4 7240 5410 3198 44.0 3178.0 8430 7500 Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2 " 12.6 # 13Cr80 40 11270 Packers and SSSV MD (ft): 9900 11276 1997 Description Summary of Proposal ŒJ Detailed Operations ProQram 0 BOP Sketch 0 14. Estimated Date for Commencing Operation: 13. Well Class after proposed work: March 25, 2005 W4/\ Exploratory 0 Developmentm Service~ 15. Well Statu~r proposed work: Oil I..YI G~A- Plugged D Abandoned D WAG 0 GINJD WI~ WDSPLD Prepared by Garry Catron 564-4657. Michael Francis Contact 16. Verbal Approval: Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Michael Francis 4-'Jv.-p ¿:I"--"':' J fd£. Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Title Phone Petroleum Engineer 564-4240 2/8/05 Other: Sundry Number: .3eC.¿;R9 BOP TestD Mechanciallntegrity Test D Location Clearance D {o ~. 404 . RBD MS 8FL MAR 0 1 2aD5 BY ORDER OF THE COMMISSION Date: ftÞf( n r, I ? r"" f: /.\ P rf-"~riH ~ l, 'to f 1\ (. ".' Form 10-403 Revised 11/2004 SUBMIT IN DUPLICATE . ~ ~L"" ) TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" þ1ultibowl 5ksi NS13 13 3/8", 68#/ft, L-80, BTC @ 3197' MD 3177' TVD ~ 4.5", 12.6#/ft, 13-Cr, Vam Ace - TUBING ID: 3.958" CAPACITY: 0.01522 BBL/FT 9-5/8" 47# L-80 BTM-C @ 10083' ¿- 4.5" X NIPPLE, @ 11200' MD' 3.813" ID 4.5" X NIPPLE, @ 11246' MD 3.813" ID 4.5" XN NIPPLE, @ 11257' MD 3.725" ID . 4.5" WLEG, @ 11269' MD 3.958" ID - B- --. , E 7", 26#/ft L-80, BTC-M @ 11488' J. PERFORATION SUMMARY REF LOG: LWO-Vision Resistivity 11/18 - 20/2001 ANGLE AT TOP PERF: 3.5 degrees Note: Refer to Production OB for historical perf data Initial Perf - Charge: 2.875", 2906 PowerJet, HMX; Penetration: 27"; 6 spf, Hole: 0.36"; Phase: 60 deg INTERVAL, INTERVAL, MO TVO Opn/Sqz OA TE 11,724' -11,864' 10,985'-11,125' Opn 12/1/2001 PBTD @ 11887' MD, 11148' TVD 4 1/2" Shoe @ 11976' MD TD @ 12000' MD 1 DATE REV. BY COMMENTS 1- inal Completion Post Perforating Updated KB Information 12/2/01 JAS 12/4/01 MJF 12/20/02 EMF )<B. ELEV = 56.19' r<B-BF. ELEV = 40.29' BASE FLANGE ELEV = 15.9' SSSV @ 1997' MD, 1997' TVD w/ HXO SVLN nipple - 3.813" ID .. ~ 6.8PPG DIESEL FREEZE PROTECTION AT +/- 4000' 4.5" GLM @ 5161'MD, 4912' TVD w/ 3.833" ID ~ - 7" LINER TOP @ 9900' MO, 9169' TVO' 4.5" Cidra PT Gauge, @ 11178' MD' 10441' TVD, 3.813" ID (Sensor ELM TVD = 10444') ~ - 7" PACKER, 13 Cr @ 11222' MD, ~'--- 10484' TVD ~ 4.5" LINER TOP @ +/-11276' MD ~ ~ 4.5", 12.6#, 13Cr Vam Ace Northstar WFI I :NS13 API NO:50-029-23017 BP Exploration (Alaska) ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS FEB 18 2005 56.19 8. Property Designation: ADL-312799 11. Present Well Condition Summary: 4. Current Well Class: Development ŒJ Stratigraphic D 9. Well Name and Number: NS13 10. Field/Pool(s): Northstar Field / Northstar Oil Pool ExploratoryD Service D r~~': ;~~;':, .'::"~, ~~, '<,\ ;r\ ,'{ ~ Stimulate D ,:'''åtb~r[r WaiverD Time E~~~~ i~~D" Re-enter Suspended WellD 5. Permit to Drill Number: 201-0860 6. API Numb 50-029-23017-00-00 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D Repair WellD PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate [K] 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 12000 feet true vertical 11260.9 feet Plugs (measured) Junk (measured) None Effective Depth measured 11910 feet true vertical 11171.1 feet None Casing Length Size MD TVD Burst Collapse LINER 1588 7" 26# L-80 9900 - 11488 9169.3 - 10749.8 7240 5410 LINER 699 4-1/2" 12.6# 13Cr80 11276 - 11975 10538.3 - 11235.9 8430 7500 PRODUCTION 10039 9-5/8" 47# L-80 44 - 10083 44.0 - 9350.4 6870 4760 SURFACE 3154 13-3/8" 68# L-80 44 - 3198 44.0 - 3178.0 4930 2270 Perforation depth: Measured depth: 11724 - 11834, 11834 - 11859, 11859 - 11864, 11864 - 11885 True vertical depth: 10985.41 -11095.2,11095.2 -11120.15,11120.15 -11125.14,11125.14 -11146.1 TubinQ ( size, ç¡rade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 40 11;CANNED FEB 2 2 2005 Packers & sssv (type & measured depth): 7" Top Packer 4-1/2" Top Packer 7" Baker 13Cr80 Packer 4-1/2" Camco WRDP-2 SSV @ 9900 @ 11276 @ 11222 @ 1997 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: Oil-Bbl 8304 8074 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 00 ~ 0 60.9 52 0 Tubing Pressure 926 1016 14. Attachments: Copies of Logs and Surveys run- Daily Report of Well Operations - ~ 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ) Service D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron .ß~ Cc~ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 30~q~ Production Technical Assistant Title Signature Form 10-404 Revised 4/2004 Phone 564-4657 ORIGINAL Date 2/16/05 RBDMS BFL FEB 1 8 2005 ) ) ~~!Æ~E ~} !Æl!Æ~[[!Æ / AI,ASIiA. OIL AlVD GAS I CONSERVATION COMMISSION / FRANK H. MURKOWSKI, GOVERNOR 333 w. -¡rtI AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279~1433 FAX (907) 276-7542 òì.aI, ~O~\{, Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: N orthstar NS 13 Sundry Number: 304-459 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Daniel T. Seamount, Jr. Commissioner ,e¡ NOÙ I -- DATED thi~ day ofI)ecerñber, 2004 Enc!. ;SÇANNEDDEC tì 1 20[}4 bp ') ') ... ,\If.''', -......~ ~...- ~..- --:...~ .~ ~..... .'I't~.\' ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 19, 2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: NOV 1 2004 Re: Sundry Notice for NS 13 to Add Perforations and Re-Perforate (Ivishak) BP Exploration Alaska, Inc. proposes to add 26' of perforations below the existing perforations and to re-perforate the bottom 30' of perforations in the NS 13 well. These perforations are expected to increase oil production from this well. The procedure includes the following maJor steps: Type Slickline Work Description Pull SSSV, Drift/tag wI dummy gun Add 26' of Ivishak Perforations from: 11,864' -11,890' MDrkb (11,125' - 11,151' TVDrkb) / Re-Perforate 30' of Ivishak from: 11,834' - 11,864' MDrkb (11,095' - 11,125' TVDrkb) Run SSSV Electric Line Slickline Sincerely, //ÝJ/ ~ r;- "/ ~dlJ:k~WJ Mic~ael J. àribi~ P .E. Senior Pet oleum Engineer BPXA, ACT, Northstar o.¡ r¡ I (: ! .~, L 'l<':'",,:i\J - ') STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION Ð APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: Suspend 0 RepairWell D Pull Tubing D Operation Shutdown 0 Plug Perforations D Perforate New Pool D 4. Current Well Class: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.19 KB 8. Property Designation: ADL-312799 11. Total Depth MD (ft): 12000 Casing Total Depth TVD (ft): 11260.9 Length Size Perforate[i] WaiverD Annular DisposalD StimulateD Time ExtensionD OtherD Re-enter Suspended Well D 5. Permit to Drill Number: 201-0860 /' 7" 26# L-80 4-1/2" 12.6# 13Cr80 9-5/8" 47# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 10985.4 11125.1 bottom top 11488 11975 10083 3198 Tubing Size: 4.5 " 12.6 # Packers and SSSV MD (ft): bottom 10749.8 11235.9 9350.4 3178.0 Tubing Grade: 13Cr80 Development ŒJ ~xPloratOry 0 Stratigraphic 0 Service 0 9. Well Name and Number: NS13 / 10. Field/Pool(s): Northstar Field 1 Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11910 11114.9 MD TVD Liner 1588 Liner 699 Production 10039 Surface 3154 Perforation Depth MD (ft): 11724 - 11864 Packers and SSSV Type: 4-1/2" BBE SSV 4-1/2" Liner Top Packer 7" 13Cr80 Packer 7" Liner Top Packer 12. Attachments: Description Summary of Proposal 00 top 9900 11276 44 44 9169.3 10538.3 44.0 44.0 6. API Number / 50-029-23017-00-00 Plugs (md): Junk (md): None None Burst Collapse 7240 8430 6870 4930 Tubing MD (ft): 40 5410 7500 4760 2270 11270 1997 11276 11222 9900 Detailed Operations Program 0 BOP Sketch 0 13. Well Class after proposed work: ExploratoryD DevelopmentOO Service D 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: Date: 15. Well Status after proposed work: Oil Œl GasD /PluggedD AbandonedD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron 564-4657. December 2, 2004 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Michael Francis 4ck.J ; Jc~-". ß ¡:::. Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP TestD Mechanciallntegrity Test D Other: Subsequent Form Required: i 9- 40 4- . Approved by: Ø!Ík~ GR!t''.' , , , ¡ ¡ , } . '< ~ ! =',.. ¡ ; \ ¡ \...,./ : Form 10-403 Revised 06/2004 Contact Title Phone Michael Francis Petroleum Engineer 564-4240 11/18/04 Sundry Number: / I I I 30'1 -'-15C{ Location Clearance D BY ORDER OF THE COMMISSION Date: // /2'[ ( 4--- AL RBDMS BFL NOV S 0 2004 SUBMIT IN DUPLICATE JI TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" i Multibowl5ksi -) NS13 13 3/8", 68#/ft, L-80, BTC @ 3197' MD 3177' TVD ..4 4.5", 12.6#/ft, 13-Cr, Vam Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBL/FT 9-5/8" 47# L-80 BTM-C @ 10083' ¿. 4.5" X NIPPLE, @ 11200' MD' 3.813" ID 4.5" X NIPPLE, @ 11246' MD 3.813" ID 4.5" XN NIPPLE, @ 11257' MD 3.725" ID 4.5" WLEG, @ 11269' MD 3.958" ID - J d 7", 26#/ft L-80, BTC-M @ 11488' JJ PERFORATION SUMMARY REF LOG: LWD-Vision Resistivity 11/18 - 20/2001 ANGLE AT TOP PERF: 3.5 degrees Note: Refer to Production DB for historical perf data Initial Perf - Charge: 2.875", 2906 PowerJet, HMX; Penetration: 27"; 6 spf, Hole: 0.36"; Phase: 60 deg INTERVAL, INTERVAL, MD TVD Opn/Sqz DATE 11,724' -11,864' 10,985'-11,125' Opn 12/1/2001 PBTD @ 11887' MD, 11148' TVD 41/2" Shoe @ 11976' MD TD @ 12000' MD J DATE REV. BY COMMENTS t-inal Completion Post Perforating Updated KB Information 12/2/01 JAS 12/4/01 MJF 12/20/02 EMF ~ . l~~:LEE~~ :6~~~~9' BASE FLANGE ELEV = 15.9' SSSV @ 1997' MD, 1997' TVD w/ HXO SVLN nipple - 3.813" ID ~ 6.8PPG DIESEL FREEZE PROTECTION AT +/- 4000' 4.5" GLM @ 5161'MD, 4912' TVD w/ 3.833" ID l\. - 7" LINER TOP @ 9900' MD, 9169' TVD' 4.5" Cidra PT Gauge, @ 11178' MD' 10441' TVD, 3.813" ID (Sensor ELM TVD = 10444') -;¡ - 7" PACKER,13 Cr @ 11222' MD, .- 10484' TVD 'E ~ ~ 4.5" LINER TOP @ +/-11276' MD 4.5", 12.6#, 13Cr Vam Ace Northstar WFJ J :NS13 API NO:50-029-23017 BP Exploration (Alaska) ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: RepairWeliD PluQ PerforationsD Stimulate IXJ OtherD Abandon 0 Alter CasingD Pull TubingD Perforate New Pool D WaiverD Time ExtensionD Change Approved Program D Operation ShutdownD Perforate D Re-enter Suspended WeliD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Œ] ExploratoryD 201-0860 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D ServiceD 50-029-23017-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56.19 NS13 8. Property Designation: 10. Field/Pool(s): ADL-312799 Northstar Field / Northstar Oil Pool 11. Present Well Condition Summary: Total Depth measured 12000 feet true vertical 11260.9 feet Plugs (measured) None Effective Depth measured 11910 feet Junk (measured) None true vertical 11171.1 feet Casing Length Size MD TVD Burst Collapse Liner 1588 7" 26# L-80 9900 - 11488 9169.3 - 10749.8 7240 5410 Liner 699 4-1/2" 12.6# 13Cr80 11276 - 11975 10538.3 - 11235.9 8430 7500 Production 10039 9-5/8" 47# L-80 44 - 10083 44.0 - 9350.4 6870 4760 Surface 3154 13-3/8" 68# L-80 44 - 3198 44.0 - 3178.0 4930 2270 Perforation decth: Measured depth: 11724 -11864 True vertical depth: 10985.41 -11125.14 Tubing ( size, grade, and measured depth): 4-112" 12.6# 13Cr80 @ 40 - 11270 RECEIVED Packers & SSSV (type & measured depth): 4-1/2" BBE SSV @ 1997 SEP 1 6 2004 4-1/2" Liner Top Packer @ 11276 Alaska Oil & Gas Cons. Commission 7" 13Cr80 Packer @ 11222 7" Liner Top Packer 9900 Anchorage 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11724.11864 Treatment descriptions including volumes used and final pressure: 67 Bbls 12% DAD Acid @ 500 psig 13 Recresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Me! Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 6717 40 7 0 1712 Subsequent to operation: 8904 52.4 10 0 1415 14. Attachments: 15. Well Class after proposed work: Exploratory 0 DevelopmentŒ ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Daily Report of Well Operations. ~ Oil[!] GasD WAGD GINJD 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 304-267 Printed Name Garry Catron Title Production Technical Assistant Signature tfr..u~ C~ - Phone 564-4657 Date 9/15/04 ... Form 10-404 Revised 4/2004 OR~G\NAL RBDMS tStL. St:~ 1 d LUU" .,'---"" ~ NS13 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/13/04 ACID I SCALE INHIB. TREATMENT: PICKLE TUBING W/17 BBLS 12% DAD ACID AND DISPLACE TO PERFS W/91 BBLS OF SW AND 63 BBLS OF DIESEL. FLOWBACK PICKLE VOLUME OF 171 BBLS TO WELL CLEAN UP TANK. PERFORM MAIN TREATMENT: 67 BBLS OF 12% DAD ACID WI SCALE INHIBITOR (20%) FOLLOWED BY 176 BBLS SW FOR DISPLACEMENT. WAIT 30 MINUTES. OVERDISPLACE WI 223 BBLS SW AND 63 BBLS OF DIESEL. ASK OPS FOR 4 HOUR SOAK TIME PRIOR TO POP. FLUIDS PUMPED BBLS 84 12% DAD Acid wI scale inhibition 490 Sea Water 4 Neat Methonal 126 Diesel 704 TOTAL Page 1 bp aOI-os-b ... "It.'". ...., ,~. .~; ~:'. ."I~t~\'~ "'~.' BP Exploration (Alaska) Inc 900 East Benson Boulevard P. O. Bùx 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 July 7,2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501 ..:~..¡:- ~i. :.' ~ID04 Dear Winton: Re: Sundry Notice for NS13 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS 13 well. This well has exhibited a steady decline and analysis of formation water indicates the formation of CaC03 scale is likely. Last summer's acidizing campaign at Northstar was very successful. The procedure includes the following major steps: . Pickle the tubing Bullhead HCI based acid treatment (which includes scale inhibitor) Flowback . . Sincerely. 71--(¡"~ j~ Michael J. Francis. P.E. Senior Petroleum Engineer BPXA. ACT. Northstar 0 9. , G 1 ~J ./\.1.- '¡J6/'t; 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 D Change Approved Program D 2. Operator Name: Suspend 0 Repair Well D Pull Tubing D Operation Shutdown 0 Plug Perforations D Perforate New Pool D 4. Current Well Class: PerforateD WaiverD Annular DisposalD StimulateŒ] Time ExtenslonD OtherD Re-enter Suspended WellD 5. Permit to Drill Number: 201-0860 / BP Exploration (Alaska), Inc. Development [!] Exploratory 0 StratigraphicD Service 0 9. Well Name and Number: NS13 ./ 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD {ft): Effective Depth TVD (ft): 11910 11114.9 MD TVD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.19 KB 8. Property Designation: ADL-312799 11. Total Depth MD (ft): 12000 Casing Total Depth TVD (ft): 11260.9 Length Size Liner 1588 Liner 699 Production 10039 Surface 3154 Perforation Depth MD (ft): 11724 - 11864 Packers and SSSV Type: 4-1/2" BBE SSV 4-1/2" Liner Top Packer 7" 13Cr80 Packer 7" Liner Top Packer 12. Attachments: Description Summary of Proposal Œ] top 9900 11276 44 44 bottom top 11488 11975 10083 3198 Tubing Size: 9169.3 10538.3 44.0 44.0 1114/ t-('LLJ 7( 11-(9-- ~,¡ 1"".1'1 6. API Number / 50-029-23017-00-00 Plugs (md): Junk (md): None None Burst Collapse bottom 10749.8 11235.9 9350.4 3178.0 Tubing Grade: 13Cr80 7" 26# L-80 4-1/2" 12.6# 13Cr80 9-5/8" 47# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 10985.4 11125.1 4.5 " 12.6 # Packers and SSSV MD (ft): 7240 8430 6870 4930 Tubing MD lft): 40 11270 5410 7500 4760 2270 1997 11276 11222 9900 Detailed Operations Program 0 BOP Sketch 0 13. Well Class after proposed work: Exploratory 0 Development Œ] Service 0 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: August 1, 2004 15. Well Status after proposed work: Oil ŒJ GasD WAG D GINJD Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Signature Michael Francis Title ~~/ 3"-'YU~)? e Phone ( Commission Use Only Petroleum Engineer 564-4240 7/8/04 Conditions of approval: Notify Commission so that a representative may witness Mechanciallntegrity Test D Plugged D Abandoned D WINJD WDSPLD Prepared by Garry Catron 564-4657. Michael Francis Sundry Number: .5 () 'Í-,;J-? 7 Location Clearance D ~~~~g~~~~ION Date: /flr!(./ ~\; 'I,! ,1..l 10(" ¡ " M8Bf'L Form 10-403 Revised 06/2004 U ~'\ i lJ i i \~ ¡--\ L- SUBMIT IN DUPLICATE TREE: ABB-VGI 5 1/8" 5ksI ~ WELLHEAD: ABB-VGI 13-5/8" Multlbowl 5ksi NS13 13 3/8". 68#/ft, L-80, BTC @ 3197' MO 3177' TVO ~ 4.5", 12.6#/ft, 13-Cr, Vam Ace TUBING 10: 3.958" CAPACITY: 0.01522 BBL/FT 9-5/8" 47# L-80 BTM-C @ 10083' H 6" 4.5" X NIPPLE, @ 11200' MO' 3.813"10 4.5" X NIPPLE. @ 11246' MO 3.813" 10 4.5" XN NIPPLE, @ 11257' MO 3.725" 10 4.5" WLEG. @ 11269' MO 3958" 10 - Ð B 7", 26#/ft L-80. BTC-M @ 11488' J. PERFORATION SUMMARY REF LOG: LWD.Vision Resistivity 11/18 - 20/2001 ANGLE AT TOP PERF: 3.5 degrees Note: Refer to Production DB for historical perf data Initial Perf - Charge: 2.875", 2906 PowerJet. HMX: Penetration: 27": 6 spr, Hole: 0.36"; Phase: 60 deg INTERVAL, INTERVAL, MD TVD Opn/Sqz DATE 11.724'-11.864' 10,985'-11,125' Opn 12/1/2001 PBTO @ 11887' MO, 11148' TVO 4 1/2" Shoe @ 11976' MO TO @ 12000' MO j OATE REV. BY COMMENTS 1- inal Completion Post Perforating Updated KB Information 12/2/01 JAS 12/4/01 MJF 12/20/02 EMF KB. ELEV = 56 19' t<.B-BF. ELEV = 40.29' BASE FLANGE ELEV = 15.9' SSSV @ 1997' MO, 1997' TVO w/ HXO SVLN nipple - 3.813" 10 ~ ~ 6.8PPG DIESEL FREEZE PROTECTION AT +/- 4000' 4.5" GLM @ 5161'MO. 4912' TVO w/ 3.833" 10 ~ - 7" LINER TOP @ 9900' MD, 9169' TVD' 4.5" Cidra PT Gauge, @ 11178' MO' 10441' TVO, 3.813" 10 (Sensor ELM TVO = 10444') k - 7" PACKER, 13 C, @ 11222' MD, ,'--- 10484' TVD E 4.5" LINER TOP @ +/-11276' MO ... ~ 4.5", 12.6#, 13Cr Vam Ace Northstar WF~ ~ :NS13 API NO:50-029-23017 BP Exploration (Alaska) bp J'~~ .' ... ." '. ..''& --." Dale: 06-15-2004 Transmittal Number: #92654 BPXA WELL DATA TRANSI'vlITTAL Please replace the previously issued materials with the data listed below. This data has been depth corrected to the primary depth control gamma ray acquired 10-31-2003. I'm sorry for any inconvenient. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojohnsojh@bp.com Log SW Name Date Contractor Run JG i -o-{( NS29 i / 04-13-2001 SCH 8 NS29 -' 04-13-2001 SCH 8 NS29 L-- 04-13-2001 SCH 8 NS29 l./ 04-13-2001 SCH 8 NS21J V 06-05-2001 SCH NS21J V" 06-05-2001 SCH NS29 f¿/06-05-2001 SCH V NS29 04-13-2001 SCH ¿,/,,/ J.t: /-¿i4 NS09. 05-25-2004 SCH "1 (J /.- O~¿. NSI3. ¡,:J-" {,1 NS08.: :::2. O:J- - ¿ I j.tJ 2 -oS if NSI5 v Top Depth Bottom Depth Log Type 165 13469 CDR* I\IEASURED DEPTH LOG; rlNAL DATA; I\IEASURED DEPTH; 13469 CDR * I\1EASURED DEPTH LOG; FINAL DATA; TRUE VERTICAL DEPTH; 13469 ADN* I\IEASURED DEPTH LOG; FINAL DATA; I\IEASURED DEPTH; 13469 ADN* I\IEASURED DEPTH LOG; PINAL DATA; TRUE VERTICAL DEPTH; 13666 PLATFORI\I EXPRESS NEUTRON POROSITY LOG; 13666 DIPOLE SHEAR SONIC II\IAGER; 165 165 165 4800 4800 4745 13680 CASED HOLE ALFS EDIT FOR .:# I 017 (, COI\IPENSATED NEUTRON AND DIPOLE SONIC DATA ON CD ROI\I lEA; OPEN HOLE ALFS EDIT FOR ~I I\IEASUREI\IENT \\'HILE DRILLlNtr D /6 ^ DATA ON CD ROI\I lEA; BP ALASKA NORTHSTAR PVT STUDY; FLUID STUDY; HARDCOPY; 161 13527 . .. -. ... ..----. --...-. f; ~ d ~ ~ Ú) - 0 :{ I --.----......----- .. Pelrulcchnical Dma Center LR2-1 900 E. Bcnson B I \'d. PO Box 196612 Anchorage. AK 99519-6612 bp .J'~.~ ... ',. .. . .--.",. BPXA WELL DATA TRANSMITTAL /Lvi) Q Vtv/J Please Sign and Return 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) PClrolcchnical Dala Cenler LR2-1 900 E. Benson BInI. PO Box 196612 Anchorage, AK 99519-6612 Dale: 06- 15 -200~ Transmillul Number: #9265~ bp ) -) o 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 fEB 072006 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. 7'i:J.CI .. 086, NS13 - Reservoir fluids - Kuparuk Sample (Sample - Downhole RFT) '0\Ck7 - J L-( t NS18 - Preliminary Recombination Results (Sample - Separator Oil and Gas) C1 . C1/~ONS31 - Reservoir Fluids -Ivishak Sample (Sample - Downhole MDT) ~O'\ --U/ . 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, 71~~~ Micqael J. Fr I Senior Petrole Engineer Northstar, BP - Alaska RECeiveD File: AOGCC "1¡~J~2~ 2004 AI~kaOi}&Gas Cons.~ ¡in", ) ') WESTPORT ..____......_.,......_......~_............_.'.M TæHNOl.QGY ŒNTER rNTERNATIONAI. Reservoir Fluids PF-02-001 January 2002 ~.~ .. NORTHSTAR WELL NS-13 KUPARUK 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 tt\¡~ 2 5 2004 .l~aska Oil & Gas Cons. Commission Anchorage 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 by client. c) 0 I - 0 8 ~F;' ( t WESTPORT TECHNOLOGY CENTER INTERNATIONAL SAMPLE SUMMARY Two gas bearing Kuparuk sands were collected by BP Exploration Alaska at the Northwest Field, Well NS-13_ The upper gas sand located at 8956.2ft. TCD was collected in a 2.75 gallon RTF cylinder. On returning to the surface a secondary transfer at 130°F was attempted which failed due to a faulty "0" ring and approximately 40cc of hydrocarbon sample was collected into a 600cc conventional sample cylinder. The lower gas sand located at 9062.5ft TVD was sampled in a 1.0 gallon RTF cylinder. The hydrocarbon sample was transferred into three high-pressure conventional sample cylinders and marked as sample 1.03, 1.04, and 1.05. Samples collected from upper (1.01) and lower (1.03, 1.04, and 1.05) portion of Northwest field NS-13 Kuparuk gas zone were shipped to Westport Technology Center for further studies. DISCUSSION After restoring the upper and lower gas samples to their respective reservoir conditions for five days, a single stage direct flash was performed to determine the compositional qualities of the hydrocarbon samples. Due to the limited sample volume of the upper gas zone (sample 1.01), only a limited PVT study of single stage direct flash and a constant composition expansion was undertaken. The compositional qualities of sample of 1.01 along with the GOR of 25732 SCF/STB are presented in Table 2. Due to the limited size of the gaseous hydrocarbon sample, its respective density was determined from the condensate's weight % using PVT simulator. A constant composition expansion performed on the sample showed a dew point pressure of 4959Psia as presented in Table 7. Compositional qualities of lower gas zone samples (1.03 - 1.05) were determined from a single stage direct flash at atmospheric conditions as presented in Tables 3 - 5. Upon comparing GOR and recombined composition of lower gas zone samples it was noted that a sample of 1.05 contained water contamination which was proved by a repeated direct flash on a sample of 1.05. To avoid any contamination while combining lower gas zone samples of 1.03 and 1.04, the sample of 1.05 was suspended from the further PVT studies. Compositional qualities of the combined lower gas zone sample of 1.03 and 1.04 are presented in Table 6. Tables 8 and 9 present constant composition expansion studies at 100 and 192°F on the combined sample of lower gas zone. A seven-stage constant volume depletion was performed on the combined sample of lower gas zone with fluid 1 gas properties summarized in Tables 10 and 11. Compositional qualities of the gas generated at each stage along with the residual liquid are summarized in Table 12. Prepared for BP-Alaska 1/14/02 PF-02-001 Page 1 WESTPORT TECHNOLOGY CENTER INTERNATIONAL Table 1 2 3 4 5 6 7 8 9 10 11 12 Prepared for BP-Alaska 1/14/2002 LIST OF SAMPLES BP Exploration Alaska, Northstar Well NS-13, Kuparuk Sample No.1 Bottle No. 1.01 - 1.14 1.01 - 1.14 1.01 CSB 6280-MA 1.03 CSB 5939-MA 1.04 CSB 6647-MA 1.05 CSB 6638-MA 1.03 CSB 5939-MA + 1.04 CSB 6647-MA 1.01 CSB 6280-MA 1.03 CSB 5939-MA + 1.04 CSB 6647-MA 1.03 CSB 5939-MA + 1.04 CSB 6647-MA 1.03 CSB 5939-MA + 1.04 CSB 6647-MA 1.03 CSB 5939-MA + 1.04 CSB 6647-MA 1.03 CSB 5939-MA + 1.04 CSB 6647-MA Work Summary Kuparuk Sample Table of Contents Kuparuk Sample Summary . GOR I C36+ Composition GOR / C36+ Composition GOR I C36+ Composition GOR / C36+ Composition GOR I C36+ Composition Constant Composition Expansion at 192°F Constant Composition Expansion at 100°F Constant Composition Expansion at 192°F Constant Volume Depletion_Fluid Properties at Cell Conditions at 192°F Constant Volume Depletion_Cumulative Mole Recovery at 192°F Constant Volume Depletion_Recombined Wellstream Analysis at 192°F PF-02-001 ~' c~ Page 2 WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 1 BP Exploration Alaska, Northstar Well NS-13, Kuparuk Sample Summary Sample Gas Gravity, GOR STO Density Bottle No. Sample No. Density (glee) at QAPI (Air = 1) (SCF/STB) (glee) Sample Depth (ft.) 6280-MA 1.01 0.3237 8000Psia /89.3°F 50.925 .. 0.6690 25732 0.7750 8956.2 5939-MA 1.03 0.4 122 1 OOOOPsÎa /130"F 47.325 0.6648 30831 0.791 0 9062.5 6647-MA 1.04 0.3976 1 OOOOPsia / 130"F 47.325 0.6643 30158 0.7910 9062.5 6638-MA 1.05 0.4090 1 OOOOPsia /131 "'F 2.433 H 0.6725 22521 1.0556 9062.5 5939-MA + 6647 -MA 1.03 + 1.04 0.3788 8000Psia / 70.2';'F 47.325 0.6637 28442 0.7910 9062.5 " API Calculated from the Composition's Condensate Weight% ** API Calculated from the Entire Sample Including Water Contamination Prepared for BP-Alaska 1/14/2002 PF-02-001 Page 3 ) ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 2 BP Exploration Alaska, Northstar Well Ns-13, Kuparuk Sample: 1.01 628()"MA, Single Stage Liquid Flash Compositions. Sample Depth: 8956.2 ft. Single Stage Flash GOR /25732 Set I STS STO Composition Flashed Gas Compositions Gas SG 0.6690 Sto Density o.m gmfcc 8000 PSIA 89.3'F Density 0.3237 Cal Mw> 132.4 Cal Mw> 19.4 Cal Mw> 22.8 Gas 011 Gas Oil Gas Oil Vol (CC) I 1.000 I ol.ool 4159.78 0.908 Density (gm/CC) 0.775 gm/cc 7.84E·04 7.843E·{¡4 0.7750 3,2626 0.7034 API 50.925 Mole%. 96.94% 3.06% 'W1% 82,26% 17.74% 25732 Scf/STB Mole 'W1 Component Wt% Mole % Wt% Mole % S 3.41 'W1% Mole % MW (Katz Et 81) Hydrogen Sulfide 0.000 0.000 GaVMcf 34.080 Nitrogen 0.000 0.000 0.236 0.163 0.194 0.158 28.013 Carbon Dioxide 0.000 0.000 2.687 1.183 2.210 1.147 44.010 Methane 0.000 0.000 71.696 86.612 58.979 83.945 16.043 Ethane 0.000 0.000 10.610 6.839 1.825 8.728 6.628 30.070 Propane 0.041 0.124 7.011 3.081 0.847 5.775 2.990 44.097 iso-Butane 0.121 0.275 1.312 0.437 0.143 1.101 0.432 58.123 n-Butane 0.540 1.231 2.320 0.774 0.244 2.004 0.787 58.123 iso-Pentane 1.087 1.995 0.791 0.212 0.078 0.843 0.267 72.150 n-Pentane 1.666 3.058 0.767 0.206 0.075 0.926 0.293 72.150 C6 5.088 8.022 0.711 0.160 0.062 1.487 0.404 84.000 Benzene 0.886 1.502 0.083 0.021 0.006 0,225 0.066 78.120 C7 11.088 15.297 0.792 0.153 0,063 2.618 0.623 96.000 Toluene 3.525 5.067 0.108 0.023 0.008 0.714 0.177 92.150 C8 13.289 16.450 0.491 0,083 0.038 2.761 0.589 107 C9 11.594 12.691 0.236 0.036 0.Q18 2,251 0.425 121 C10 8.669 8.568 0.079 0.011 0.006 1.603 0.273 134 C11 6.099 5.495 0.024 0.003 0.002 1,102 0.171 147 C12 4.900 4.031 0.007 0.001 0.001 0.875 0.124 161 C13 4.807 3.638 0.039 0,002 0.885 0.115 175 C14 3.985 2.778 0.707 0.085 190 C15 3.330 2.141 100.00 100.00 0.591 0.065 206 C16 2.482 1.481 0.440 0.045 222 C17 2.016 1.126 Heating Values BTUI CF 0.357 0.034 237 C18 1.743 0.920 Grossi 1156 0.309 0.028 251 C19 1.369 0.689 Net 1046 0.243 0.021 263 C20 1.014 0.488 0.180 0.015 275 C21 0.974 0.443 0.173 0.014 291 C22 0.658 0.286 MW 19.377 0.117 0.009 305 C23 0.566 0.236 SG 06690 0.100 0.007 318 C24 0.397 0.159 Z STP 09934 0.070 0.005 331 C25 0.324 0.125 0.058 0.004 345 C26 0.248 0.092 C.91,~ Cr::iç¡¡1 T .? P 0.044 0.003 359 C27 0.200 0.071 CF:, ·80 0.035 0.002 374 C28 0.161 0.055 (PSlt\'. 6G£\ 0.029 0.002 388 C29 0.127 0.042 0.022 0.001 402 C30 0.098 0.031 0.017 0.001 416 C31 0.073 0.023 0.013 0.001 430 C32 0.056 0.017 0.010 0.001 444 C33 0.045 0.013 0.008 0.000 458 C34 0.036 0.010 0.006 0.000 472 C35 0.032 0.009 0.006 0.000 486 C36 6.663 1.321 1.182 0.040 668 100.000 100.000 100.000 100.000 P'repared for BP·Alaska 1 '1 412002 PF.Q2-Q01 Page 4 Page 5 PF·02·oo1 Prepared tor BP·Alaska 1/14/2002 Single Stage Flash GOn ['\D'-" S j~"(! _.'~ ,~,.. ,... c,.,::, I " STO Composition Flashed Gas Compositions G~~s SG 0.;:;648 Sto Density 0.791 gm/cc : COC'Ü PSIt>, 13Cf :)f:nsily OA1?? Cal Mw> 170.9 Cal Mw> 19.3 C~I Mw;, 2'2.3 Gas 011 Gas 011 GilS Oil Vol (CC>I I 1.000 I I 01.001 I 6302.74 I 1.148 Density (gmlCC) 0.791 gm/cc 7.88E-04 7.878E·04 0.7910 4.9651 0.9019 API 47.235 Mole ./" 97.98% 2.02'% W1 "j,., 8,4 . 54 ~,.'ó 15.4 G% 30831 3d/STB Mole Wt Component Wt% Mole % Wt% Mole % S 3.35 Wt% Mole % MW (Katz Et al) Hydrogen Sulfide 0.000 0.000 GallMcf 34.080 Nitrogen 0.000 0.000 0.229 0.157 0.194 0.154 28.013 Carbon Dioxide 0.000 0.000 2.878 1.259 2.433 1.234 44.010 Methane 0.000 0.000 72.206 86.677 61.045 84.913 16.043 Ethane 0.000 0.000 10.936 7.004 1.870 9.245 6.861 30.070 Propane 0.001 0.003 6.886 3.007 0.827 5.822 2.946 44.097 iso-Butane 0.000 0.000 1.258 0.417 0.136 1.064 0.408 58.123 n-Butane 0.001 0.002 2.171 0.719 0.227 1.836 0.705 58.123 iso-Pentane 0.000 0.001 0.695 0.185 0.068 0.588 0.182 72.150 n-Pentane 0.001 0.002 0.655 0.175 0.063 0.554 0.171 72 .150 C6 0.010 0.021 0.575 0.128 0.050 0.488 0.130 84.000 Benzene 0.000 0.000 0.070 0.017 0.005 0.059 0.017 78.120 C7 0.032 0.057 0.636 0.122 0.050 0.543 0.126 96.000 Toluene 0.009 0.016 0.124 0.026 0.009 0.106 0.026 92.150 C8 0.888 1.418 0.392 0.066 0.030 0.469 0.098 107 C9 7.477 10.563 0.189 0.028 0.014 1.316 0.243 121 C10 14.170 18.076 0.064 0.009 0.005 2.245 0.374 134 CII 13.209 15.360 0.019 0.002 0.001 2.058 0.312 147 C12 11.700 12.422 0.005 0.001 0.001 1.813 0.251 161 C13 11.449 11.184 0.010 0.001 1.778 0.227 175 C14 9.359 8.420 1.447 0.170 190 C15 7.662 6.358 100.00 100.00 1.184 0.128 206 C16 5.631 4.336 0.870 0.087 222 C17 4.457 3.215 Heating Values BTU/CF 0.689 0.065 237 C18 3.670 2.500 Grossi 1148 i 0.567 0.050 251 C19 2.789 1.813 Net 1039 0.431 0.037 263 C20 1.939 1.206 0.300 0.024 275 C21 2.059 1.209 0.318 0.024 291 C22 1.042 0.584 ~.,1VV '9.2:'6 0.161 0.012 305 C23 0.942 0.506 $G 06(,1:8 0.146 0.010 318 C24 0.522 0.269 7 S'f!' 0.8835 ._h._ 0.081 0.005 331 C25 0.378 0.187 0.058 0.004 345 C26 0.216 0.103 ~~I 0.033 0.002 359 C27 0.168 0.077 0.026 0.002 374 C28 0.099 0.044 0.015 0.001 388 C29 0.059 0.025 0.009 0.001 402 C30 0.032 0.013 0.005 0.000 416 C31 0.011 0.005 0.002 0.000 430 C32 0.005 0.002 0.001 0.000 444 C33 0.004 0.001 0.001 0.000 458 C34 0.004 0.001 0.001 0.000 472 C35 0.003 0.001 0.000 0.000 486 C36 0.004 0.001 0.001 0.000 668 100.000 100.000 100.000 100.000 BP Exploration Alaska, Northstar Well Ns-13, Kuparuk Sample: 1.03 5939-MA, Single Stage Liquid Flash Compositions, Sample Depth: 9062.5 ft. TABLE 3 WESTPORT TECHNOLOGY CENTER INTERNATIONAL ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL ) TABLE 4 BP Exploration Alaska, Northstar Well Ns-13, Kuparuk Sample: 1.04 6647-MA, Single Stage Liquid Flash Compositions, Sample Depth 9062.5 ft. STO Composition Sto Density 0.791 gmlcc Cal Mw> 180.0 Gas Oil Vol (CC) 1.000 Density (gmfCC) 0.791 gmlcc API 47.235 Component Wt% Mole % Hydrogen Sulfide 0.000 0.000 Nitrogen 0.000 0.000 Carbon Dioxide 0.000 0.000 Methane 0.000 0.000 Ethane 0.000 0.000 Propane 0.000 0.001 iso·Butane 0.000 0.000 n-Butane 0.000 0.001 iso-Pentane 0.000 0.001 n·pentane 0.000 0.001 C6 0.009 0.019 Benzene 0.000 0.000 C7 0.028 0.052 Toluene 0.000 0.000 C8 0.048 0.081 C9 2.478 3.687 C10 10.452 14.043 C11 13.433 16.452 C12 13.083 14.629 C13 13.256 13.637 C14 10.884 10.313 C15 8.923 7.799 C16 6.440 5.222 C17 5.085 3.863 C18 4.185 3.002 C19 3.141 2.150 C20 2.148 1.406 C21 2.227 1.378 C22 1.223 0.722 C23 1.045 0.592 C24 0.584 0.317 C2S 0.437 0.228 C26 0.276 0.139 C27 0.203 0.098 C28 0.137 0.063 C29 0.096 0.043 C30 0.051 0.022 C31 0.032 0.014 C32 0.005 0.002 C33 0.003 0.001 C34 0.002 0.001 C3S 0.001 0.001 C36 0.086 0.023 100.000 100.000 P",pared lor BP-Alaska 1'1412002 Single Slase Flash GOR. 1:30158. ScflSTB Gas so 0.6643 10000 PSIA 130"F ()e~$¡ty 0.3976 CaIMw>. ~ Flashed Gas Compositions Cal Mw> 19.2 Gas 011 01.001 7.88E-04 Gas ¡¡;~¡;'5.7~ ?~~l8.E,,()~ 4... !~if.¡, Mole % 98.04% Wt % ... ·84..25~;, Wt% Mole % S 3.34 GaI/Mcf 0.250 0.172 2.847 1.244 72.319 86.715 10.880 6.961 1.858 6.931 3.024 0.831 1.272 0.421 0.138 2.189 0.725 0228 0.690 0.184 0.067 0.648 0.173 0.063 0.556 0.124 0.048 0.067 0.017 0.005 0.608 0.117 0.048 0.114 0.024 0.008 0.367 0.062 0.028 0.171 0.026 0.013 0.058 0.008 0.004 0.018 0.002 0.001 0.005 0.001 0.001 0.010 0.001 100.00 100.00 Heating Values BTU/CF Gross~ . 1147 I Net 1038 !...IW 19.239 SG 0.6643 Z SlP 0.9935 Code Çrl1iÇ,11 T& P Cf')1 ·81 (PSI^) 669 Wt% 0.211 2.399 60,929 9.166 5.839 1.072 1.844 0.581 0.546 0.470 0.056 0.517 0.096 0.317 0.534 1.695 2.131 2.065 2.096 1.714 1.405 1.014 0.801 0.659 0.495 0.338 0.351 0.193 0.165 0.092 0.069 0.044 0.032 0.022 0.015 0.008 0.005 0.001 0.000 0.000 0.000 0.014 100.000 PF-û2-OO1 011 O,~a.:~ ¡Ù~il:l 30158 Scf/STB Mole % 0.168 1.220 85.007 6.823 2.964 0.413 0.710 0.180 0.169 0.125 0.016 0.120 0.023 0.066 0.099 0.283 0.324 0.287 0.268 0.202 0.153 0.102 0.076 0.059 0.042 0.028 0.027 0.014 0.012 0.006 0.004 0.003 0.002 0.001 0.001 0.000 0.000 0.000 0.000 0.000 0.000 0.000 100.000 i ,\, \~ Mole Wt MW (Katz Et al) 34.080 26.013 44.010 16.043 30.070 . 44.097 58.123 58.123 72.150 72.150 84.000 76.120 96.000 92.150 107 121 134 147 16t 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 6 WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 5 BP Exploration Alaska, Northstar Well NS-13, Kuparuk Sample: 1.05 6638-MA, Single Stage Liquid Flash Compositions, Sample Depth: 9062.5 ft. Single Stage Flastl GOIl 122521 ScJ!sm STO Composition Flashed Gas Compositions Gas SG 0.6725 Sto Density 1 .0556 gmlcc 10000 PSIA 131"F Density 0.4090 Cal Mw> 196.2 Cal Mw> 19.5 Ga Mw> 2~iO Gas Oil Gas Oil Gas Oil Vol (CC) I 1.000 I 01.001 4807.43 1.199 Density (gmlCC) 1.0556 gmlcc 8.06E-04 8.064E-04 1.0556 3.5768 1.2652 API 2.433 Mole 0/. 96.86% 3. '4';"~ Wt%' 24.60% 22521 Set/STB Mole Wt Component Wt% Mole % Wt% Mole % S 3.64 Wt% Mole % MW (Katz Et al) Hydrogen Sulfide 0.000 0.000 Gal/Met 34.080 Nitrogen 0.000 0.000 0.320 0.222 0.241 0.216 28.013 Carbon Dioxide 0.000 0.000 2.722 1.205 2.052 1.167 44.010 Methane 0.000 0.000 70.493 85.599 53.149 82.900 16.043 Ethane 0.000 0.000 11 .358 7.358 1.964 8.563 7_126 30.070 Propane 0.000 0.001 8.391 3.707 1.019 6.326 3.590 44.097 iso-Butane 0.000 0.000 1.524 0.511 0.167 1.149 0.495 58.123 n-Butane 0.000 0.001 2.154 0.722 0.227 1.624 0.699 58.123 iso-Pentane 0.000 0.000 0.621 0.168 0.061 0.468 0.162 72.150 n-Pentane 0.000 0.001 0.567 0.153 0.055 0.428 0.148 72.150 C6 0.001 0.003 0.491 0.111 0.043 0.371 0.110 84.000 Benzene 0.000 0.000 0.061 0.015 0.004 0.046 0.015 78.120 C7 0.028 0.057 0.543 0.106 0.044 0.416 0.108 96.000 Toluene 0.041 0.088 0.115 0.024 0.008 0.097 0.026 92.150 C8 0.143 0.263 0.339 0.058 0.026 0.291 0.068 107 C9 2.098 3.402 0.179 0.027 0.014 0.651 0.135 121 C10 8.044 11.778 0.068 0.009 0.005 2.030 0.379 134 C11 10.428 13.919 0.023 0.003 0.002 2.583 0.440 147 C12 10.612 12.933 0.006 0.001 0.001 2.616 0.407 161 C13 11 .343 12.718 0.025 0.001 2.810 0.402 175 C14 9.698 10.015 2.386 0.314 190 C15 8.360 7.962 100.00 100.00 2.057 0.250 206 C16 6.235 5.511 1.534 0.173 222 C17 5.371 4.447 Hf:atlng V;.lu,,'s B1U/CF 1.322 0.140 237 C18 4.439 3.470 GrossI 11fìO 1.092 0.109 251 C19 3.636 2.713 t~(è' iO:;1) 0.895 0.085 263 C20 2.611 1.863 0.642 0.058 275 C21 4.085 2.754 1.005 0.086 291 C22 1.829 1.177 M"l,' 1947F\ 0.450 0.037 305 C23 1.845 1.138 SG ()f17?~) 0.454 0.036 318 C24 0.866 0.514 Z STf) O<J9J:' 0.213 0.016 331 C25 0.762 0.433 0.188 0.014 345 C26 0.509 0278 C"I~ Crllic;,1 T & f> 0.125 0.009 359 C27 0.469 0.246 ----.-( F' ~~·I:; \·:~:-,·:·-.-.t~~.=-.-.:-.-.j 0.115 0.008 374 C28 0.375 0.190 0.092 0.006 388 C29 0.331 0.162 0.082 0.005 402 C30 0.293 0.138 0.072 0.004 416 C31 0.294 0.134 0.072 0.004 430 C32 0.281 0.124 0.069 0.004 444 C33 0.283 0.121 0.070 0.004 458 C34 0.298 0.124 0.073 0.004 472 C35 0.302 0.122 0.074 0.004 486 C36 4.088 1.201 1.006 0.038 668 100.000 100.000 100.000 100.000 Prepared for BP-Alaska 1/14/2002 PF-02-û01 Page 7 ) ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 6 BP Exploration Alaska, Northstar Well NS-13, Kuparuk Sample: (1.03+1.04) 5939-MA + 6647-MA. Single Stage liquid Flash Compositions, Sample Depth: 9062.5 fl Single Stage Flash GOR 128442 Scf/STB STO Composition Flashed Gas Compositions GnS SG 0.6637 Sto Density 0.791 gm/cc 8000 PSIA 70.2·F DensUy 0.3788 Cal Mw> 175.4 CaI Mw> 19.2 Cal MIA.'> 22.6 Gas 011 Gas 011 Gas Oil Vol (CC)I I 1.00.0 I 01..001 4937.61 0.975 Oenslty (gmlCC) 0.791 gmlcc 7.77E-Q4 7.767e-{}4 0.791.0 . .. . 3.8350 0.7710 API 47.235 Mole % 97.84% 2.16% Wt% 16.74% 28442 Scf/STB Mole Wt Component Wt% Mole 0/. Wt% Mole % I 3.35 Wt% Mole % MW (Katz Et 81) Hydrogen Sulfide 0.000 0.000 GaVMcf 34.080 Nitrogen 0.000 0.000 0.239 0.164 0.199 0.161 28.013 Carbon ~ioxide 0.000 0.000 2.862 1.251 2.383 1.225 44.010 Methane 0.000 0.000 72.263 86.696 60.170 84.812 16.043 Ethane 0.000 0.000 10.908 6.982 1.864 9.082 6.830 30.070 Propane 0.000 0.002 6.908 3.015 0.829 5.752 2.950 44.097 iso-Butane 0.000 0.000 1.265 0.419 0.137 1.053 0.410 58.123 n-Butane 0.001 0.002 2.180 0.722 0.227 1.815 0.706 58.123 iso-Pentane 0.000 0.001 0.692 0.184 0.067 0.577 0.181 72.150 n-Pentane 0.001 0.001 0.651 0.174 0.063 0.543 0.170 72.150 C6 0.010 0.020 0.565 0.126 0.049 0.472 0.127 84.000 Benzene 0.000 0.000 0.068 0.017 0.005 0.057 0.017 78.120 C7 0.030 0.055 0.622 0.119 0.049 0.523 0.123 96.000 Toluene 0.004 0.008 0.119 0.025 0.008 0.100 0.024 92.150 C8 0.468 0.767 0.379 0.064 0.029 0.394 0.083 107 C9 4.977 7.214 0.180 0.027 0.013 0.983 0.184 121 Cl0 12.311 16.112 0.061 0.008 0.005 2.112 0.356 134 Cll 13.321 15.892 0.018 0.002 0.001 2.245 0.345 147 C12 12.391 13.497 0.005 0.001 0.001 2.078 0.292 161 C13 12.353 12.379 0.005 0.001 2.072 0.268 175 C14 10.121 9.342 1.694 0.202 190 CiS 8.293 7.060 100.00 100.00 1.388 0.152 206 C16 6.035 4.767 1.010 0.103 222 C17 4.771 3.530 Heating Values BTU/CF 0.799 0.076 237 C1S 3.928 2.744 Grassl 1148 0.657 0.059 251 C19 2.965 1.977 Net 1038 0.496 0.043 263 C20 2.044 1.303 0.342 0.028 275 C21 2.143 1.291 0.359 0.028 291 C22 1.132 0.651 MW 19.248 0.190 0.014 305 C23 0.993 0.548 SG O.tìß37 0.166 0.012 318 C24 0.553 0.293 Z STP 0.9935 0.092 0.006 331 C25 0.408 0.207 0.068 0.004 345 C26 0.246 0.120 Cille. Cnt1cal T & P 0.041 0.003 359 C27 0.186 0.087 (VFì\ ·81 0.031 0.002 374 C28 0.118 0.053 (PSIAI 6t3~1 0.020 0.001 388 C29 0.077 0.034 0.013 0.001 402 C30 0.042 0.018 0.007 0.000 416 C31 0.022 0.009 0.004 0.000 430 C32 0.005 0.002 0.001 0.000 444 C33 0.003 0.001 0.001 0.000 458 C34 0.003 0.001 0.000 0.000 472 C35 0.002 0.001 0.000 0.000 486 C36 0.045 0.012 0.008 0.000 668 100.000 100.000 100.000 100.000 Prepared for BP-Alaska 1/1412002 PF-02-Q01 Page 8 WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 7 BP Exploration Alaska, Northstar Well NS-13, Kuparuk Sample: 1.01 6280-MA, Constant Composition Expansion at 192°F, Sample Depth: 8956.2 ft. Pressure Sample Vol Relative liquid Volume liquid Volume (psia) (cc) Volume (cc) Fraction 8034 37.339 0.7953 7734 37.846 0.8061 7466 38.440 0.8187 7202 38.978 0.8302 6958 39.485 0.8410 6728 40.119 0.8545 6500 40.736 0.8676 6293 41.417 0.8821 6094 42.035 0.8953 5912 42.724 0.9099 5731 43.357 0.9234 5564 44.094 0.9391 5401 44.783 0.9538 5244 45.503 0.9691 5097 46.240 0.9848 4959 46.952 1 .0000 Psat I 4827 47.784 1 .01 77 4702 48.449 1.0319 4580 49.130 1 .0464 4361 50.840 1.0828 4160 52.558 1 .1194 3980 54.007 1.1503 3816 55.702 1 . 1864 3665 57.484 1.2243 3536 59.154 1 .2599 0.4197 7.0946E-03 3411 60.968 1 .2985 0.6335 1.0390E-02 3194 64.468 1 .3730 0.8156 1.2651 E-02 3097 66.265 1.4113 0.7602 1.1472E-02 2914 69.955 1 .4899 0.9977 1.4262E-02 2796 72.687 1.5481 0.9977 1.3726E-02 2592 78.333 1 .6684 1 .0611 1.3546E-02 Prepared for BP-Alaska 1/14/2002 PF-02-001 Paae 9 ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 8 ) BP Exploration Alaska, Northstar Well NS-13, Kuparuk Sample: (1.03 + 1.04) 5939-MA + 6647-MA, Constant Composition Expansion at 100°F, Sample Depth: 9062.5 ft. Pressure (Psi a) 8238.56 7908.06 7607.32 7258.34 7005.85 6752.33 6446.46 6232.97 5996.90 5833.70 5663.32 5532.97 5431.35 5336.92 5162.44 5079.30 5013.61 4938.68 4860.67 4796.01 4723.14 4658.4 7 4610.23 4553.78 4478.85 4427.53 4368.00 4334.13 4129.88 3976.94 3804.51 3561.25 3371.37 3178.40 2932.07 2668.28 2186.90 2020.62 Prepared for BP-Alaska 1/14/2002 Sample Volume (cc) 34.7072 35.1585 35.5909 36.0937 36.4857 36.9212 37.4913 37.8872 38.3940 38.7582 39.1621 39.4867 39.7797.. 40.0648 40.5874 40.8408 41.0308 41.3080 41.5772 41.7751 42.0285 42.2423 42.3849 42.5907 42.7966 43.0104 43.3509 43.6122 44.5466 45.4334 46.4549 48.2841 50.0736 52.1799 55.5611 60.3200 73.8447 80.7495 Relative Volume (Vol.! Psat Vol.) 0.7958 0.8062 0.8161 0.8276 0.8366 0.8466 0.8597 0.8687 0.8803 0.8887 0.8980 0.9054 0.9121 0.9187 0.9306 0.9365 0.9408 0.9472 0.9533 0.9579 0.9637 0.9686 0.9719 0.9766 0.9813 0.9862 0.9940 1. 0000 1.0214 1.0418 1. 0652 1.1071 1.1482 1. 1965 1.2740 1.3831 1.6932 1.8515 Liquid Volume (cc) 0.00000796 0.00250581 0.01087017 0.04047183 0.19125339 0.39633760 0.63665160 0.98952402 1.40072566 2.10700059 2.43955615 PF-02-001 Liquid Vol. Fraction (Liq. Vol. I Vol.) 0.0000002 0.0000561 0.0001843 0.0006910 0.0032962 0.0047367 0.0076556 0.0106200 0.0134395 0.0175548 0.0141577 Psat Paae 10 WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 9 BP Exploration Alaska, Northstar Well NS-13, Kuparuk Sample: (1.03 + 1.04) 5939-MA + 6647-MA, Constant Composition Expansion at 192°F, Sample Depth: 9062.5 ft. Pressure 8238.56 7872.13 7473.89 7152.62 6870.36 6530.63 6231.94 6041.03 5890.15 5763.91 5601 .73 5490.88 5345.13 5182.96 5100.85 4993.08 4872.99 4784.72 4729.29 4653.34 4623.58 4565.07 4513.75 4474.75 4429.59 4370.05 4299.23 4220.20 4081.64 3955.39 3769.61 3596.15 3355.97 3144.53 2653.91 2422.97 2167.40 (Psia) Sample Volume 38.6870 39.5580 40.5296 41 .3159 42.1077 43.0975 44.0240 44.6891 45.2513 45.7660 46.4470 46.9696 47.6823 48.4979 48.9809 49.6223 50.3666 50.9288 51.2693 51.7682 51.9820 52.3383 52.6629 52.8847 53.2568 53.7557 54.2466 54.8880 56.1708 57.4061 59.5836 61.7849 65.5303 69.2045 81.3355 88.8580 99.9358 Prepared for BP-Alaska 1/14/2002 (cc) Relative Volume (Voll Psat Vol.) 0.7197 0.7359 0.7540 0.7686 0.7833 0.8017 0.8190 0.8313 0.8418 0.8514 0.8640 0.8738 0.8870 0.9022 0.9112 0.9231 0.9370 0.9474 0.9537 0.9630 0.9670 0.9736 0.9797 0.9838 0.9907 1.0000 1.0091 1.0211 1.0449 1.0679 1 . 1 084 1 .1494 1 .2190 1 .2874 1.5131 1 .6530 1.8591 PF-02-001 Liquid Volume (cc) 0.00000000 0.00011198 0.00036272 0.00191117 0.00590106 0.02552850 0.06761389 0.17226043 0.27189932 0.61164053 0.75224787 0.93187575 Liquid Vol. Fraction (Liq. Vol. I Vol.) 0.0000000 0.0000021 0.0000046 0.0000296 0.0000739 0.0003573 0.0007498 0.0019218 0.0021092 0.0035945 0.0051755 0.0047229 Psat Page 11 ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 10 ) BP Exploration Alaska, Northstar Well NS..13, Kuparuk Sample: (1.03 + 1.04) 5939-MA + 6647-MA Constant Volume Depletion Fluid Properties at Cell Conditions at 192°F, Sample Depth: 9062.5 ft. Stage 1 2 3 4 5 6 7 STO Avg. M.W, (g/mol) 26.542 22.202 20.971 20.345 20.317 20.450 22.559 158.115 Pressure (psi a) 3702 3005 2300 1600 1001 600 41 15 * Measured Values Gas Z-Factors .20 I I I .00 ",:1,77,00 ~{~ 0.80 . ~ 0 - 0 0.60 . ca U. I N 0.40 . ';.""tr,~;~Ü"j ,,', 0.20 . 0.00 . .:: ': i~: 1 111I1t.! : c;, '..'~ ~ .~c·::":;· Pressure (psia) Prepared for BP-Alaska 1/14/2002 PF·02-001 Ga,s Density (g(cc) 0.2665 0.1766 0.1273 0.082.5 0.0492 0.0280 0.0194 Gas Z-Factor * 1 .1270 0.9200 0.8100 0.7780 0.7950 0.8479 1.0000 1. =:'1111 5111!1.1 ~:'1 ï-::' 41. It' \t'I Page 12 Page 13 0_0953 0_2133 0.3551 0.5072 0.6416 0.7281 0.8472 0.8509 0.0953 0.1179 0.1418 0.1522 0.1344 0.0865 0.1191 0_0037 Avg. M.W. (g/mol) 26.542 22.202 20.971 20.345 20.317 20.450 22.559 158.115 Moles Produced Cumulative Moles Cumulative Mass (g) 2.5307 5.1489 8.1226 11.2185 13.9492 15.7180 18.4040 18.9850 PF-02-001 50.12 03788 18.985 100.000 22.300 0.8513 99.946 Mass Produced (g) 2.5307 2.6182 2.9737 3.0959 2.7307 1.7688 2.6860 0.5810 Prepared for BP-Alaska 1/14/2002 * Charging Conditions 8000psi /70.2°F Volume Charged (ee) Density at Charging Conditions (g/ee)" M<1sS Chargeci (g) CVD Mass Balance (%) Avg. M.W. of Sample from a Direct Flash (g/mol) Moles Produced from a Direct Flash at Conditions Direct Flash I CVD Moles Produced Correlation (~/~) 3702 3005 2300 1600 1001 600 41 15 1 2 3 4 5 6 7 STO Pressure (psi a) Stage BP Exploration Alaska, Northstar Well NS-13, Kuparuk Sample: (1.03 + 1.04) 5939-MA + 6647-MA Constant Volume Depletion at 192°F Cumulative Recovery, Sample Depth: 9062.5 ft. TABLE 11 WESTPORT TECHNOLOGY CENTER INTERNATIONAL ) ) WESTPORT TECHNOLOGY CENTER INTERNATIONAL TABLE 12 BP Exploration Alaska, Northstar Well NS-13, Kuparuk Sample: (1.03 + 1.04) 5939-MA + 6647-MA, Constant Volume Depletion at 192°F, Sample Depth: 9062.5 ft. Recombined Wellstream Analysis Stage 1 2 3 4 5 6 7 STO Pressure (psia) 3702 3005 2300 1600 1001 600 41 15 Temperature ("F) 192 192 192 192 192 192 192 192 Gas Gravity (Air = 1) * 0.7246 0.7146 0.7048 0.7049 0.7038 0.7085 0.7372 Avg. M.W. (gImol) ** 26.542 22.202 20.971 20.345 20.317 20.450 22.559 158.115 Component Mole % Mole % Mole % Mole % Mole % Mole % Mole % Mole % Wei~ht % Nitrogen N2 0.1437 0.1706 0.2476 0.2340 0.1600 0.2110 0.2059 0.0000 0.0000 Carbon Dioxide CO2 1.1164 1.1625 1.1682 1.1640 1.1710 1.1670 1.1536 0.0000 0.0000 Methane C1 79.9315 83.6749 84.7516 85.3260 85.3400 85.0170 82.3279 0.0000 0.0000 Ethane C2 6.6087 6.8831 6.8635 6.8850 6.9130 6.9640 7.0033 0.0010 0.0002 Propane C3 2.9474 3.0509 3.0064 2.9990 3.0440 3.0950 3.2737 0.0073 0.0020 IsoButane i-C4 0.4715 0.4798 0.4618 0.4590 0.4690 0.4830 0.5478 0.0083 0.0031 Normal Butane n-C4 0.8934 0.8975 0.8573 0.8480 0.8670 0.9010 1.0648 0.0351 0.0129 Iso Pentane j-C5 0.3315 0.3157 0.2920 0.2840 0.2900 0.3080 0.4130 0.0728 0.0332 Normal Pentane n-C5 0.3669 0.3402 0.3118 0.3020 0.3060 0.3270 0.4614 0.1453 0.0663 Hexanes C6 0.5263 0.4057 0.3524 0.3260 0.3240 0.3530 0.6587 0.8350 0.4436 Benzene C6H6 0.0950 0.0648 0.0530 0.0470 0.0470 0.0520 0.1058 0.2917 0.1441 Heptanes C7 1.0105 0.6142 0.4977 0.4310 0.4200 0.4570 0.9733 3.8965 2.3658 Toluene C7H8 0.5018 0.2105 0.1480 0.1110 0.1030 0.1110 0.3109 4.1358 2.4117 Octanes C8 1.3063 0.5699 0.4150 0.3170 0.3020 0.3150 0.8929 9.4511 6.3957 Nonanes C9 1.3549 0.4304 0.2703 0.1760 0.1610 0.1570 0.3719 13.9600 10.6831 Decanes C 1 0 1.0268 0.2606 0.1353 0.0630 0.0580 0.0570 0.1353 13.4656 11 .4118 Undecanes C11 0.6375 0.1560 0.0666 0.0210 0.0190 0.0190 0.0460 10.5654 9.8227 Dodecanes C 12 0.3638 0.0993 0.0365 0.0050 0.0040 0.0040 0.0167 8.6690 8.8272 Tridecanes C 13 0.2119 0.0846 0.0258 0.0020 0.0020 0.0020 0.0081 8.3630 9.2560 Tetradecanes C14 0.0827 0.0488 0.0152 0.??oo 0.0000 0.0000 0.0034 6.5958 7.9258 Pentadecanes C 15 0.0313 0.0294 0.0100 0.??oo 0.0000 0.0000 0.0022 5.1715 6.7377 Hexadecanes C16 0.0102 0.0130 0.0055 0.0000 0.0000 0.0000 0.0017 3.6139 5.0740 Heptadecanes C 17 0.0044 0.0060 0.0027 0.0000 0.0000 0.0000 0.0016 2.7548 4.1292 Octadecanes C 18 0.0047 0.0035 0.0014 0.??oo 0.0000 0.0000 0.0014 2.2132 3.5133 Nonadecanes C19 0.0038 0.0019 0.0005 0.??oo 0.0000 0.0000 0.0008 1.6132 2.6833 Eicosanes C20 0.0029 0.0012 0.0001 0.0000 0.0000 0.0000 0.0005 1.0796 1.8776 Henicosanes C21 0.0020 0.0009 0.0000 0.??oo 0.??oo 0.0000 0.0003 0.8871 1 .6327 Docosanes C22 0.0013 0.0008 0.0000 0.??oo 0.0000 0.0000 0.0001 0.7284 1.4051 Tricosanes C23 0.0010 0.0005 0.0000 0.??oo 0.0000 0.0000 0.0001 0.3749 0.7541 Tetracosanes C24 0.0003 0.0005 0.0000 0.??oo 0.0000 0.0000 0.0001 0.3413 0.7144 Pentacosanes C25 0.0003 0.0005 0.0000 0.??oo 0.0000 0.0000 0.0002 0.4135 0.9022 Hexacosanes C26 0.0001 0.0004 0.0000 0.??oo 0.0000 0.0000 0.0002 0.1095 0.2485 Heptacosanes C27 0.0002 0.0005 0.0000 0.??oo 0.0000 0.0000 0.0002 0.0801 0.1896 Octacosanes C28 0.0003 0.0005 0.0000 0.??oo 0.0000 0.0000 0.0003 0.0523 0.1284 Nonacosanes C29 0.0001 0.0006 0.??oo 0.0000 0.0000 0.0000 0.0003 0.0344 0.0874 Triacontanes C30 0.0001 0.0005 0.??oo 0.??oo 0.0000 0.0000 0.0003 0.0163 0.0567 Hentriacontanes C31 0.0001 0.0005 0.0001 0.??oo 0.0000 0.0000 0.0005 0.0099 0.0345 Dotriacontanes C32 0.0002 0.0006 0.0001 0.??oo 0.0000 0.0000 0.0005 0.0056 0.0197 Tritriacontanes C33 0.0003 0.0007 0.0001 0.??oo 0.0000 0.0000 0.0004 0.0010 0.0033 Tetriacontanes C34 0.0006 0.0009 0.0001 0.??oo 0.??oo 0.0000 0.0007 0.0000 0.0000 Pentatriacontanes C35 0.0006 0.0013 0.0002 0.??oo 0.0000 0.0000 0.0007 0.0000 0.0000 Hexatriacontanes+ C36+ 0.0066 0.0154 0.0034 0.??oo 0.0000 0.0000 0.0127 0.0009 0.0032 Total 100.0000 100.0000 100.0000 100.??oo 100.??oo 100.0000 100.??oo 100.0000 100.0000 . Gas Gravity (Air = 1) is Based on Gas Portion of the Sample Only .. Average Molecular Weight (glmol) is Based on the Mathematically Recombined Gas and Oil Fractions Together Prepared for BP-Alaska 1/14/2002 PF-02-001 Page 14 ~ J~ Àòac.( DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2010860 Well Name/No. NORTHSTAR UNIT NS-13 Operator BP EXPLORATION (ALASKA) INC 5jt.....b L' J~ Aò~ ( API No. 50-029-23017-00-00 MD 12000 /' TVD 11261 r Completion Date 12/2/2001 /' Completion Status 1-01L Current Status 1-01L UIC N ------ ----- .----- REQUIRED INFORMATION Mud Log No Samples No Directional Survey -~ - 'i ~. ~ ------- --- --------- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) ra- Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ---------- - ~ C rro551 :Jri¡j9CtipnlRøsistivity.. 1-5 165 12012 Open 2/5/2002 i~ ~s Lateral Array 2/5 FINAL 3197 9950 Case 7/27/2001 3197-9950 BL, Sepia I //'10332 1J2Ð T 169 11490 Open 9/25/2001 169-11490 I 1£9' C ~551 1-5 165 12012 Open 2/5/2002 ~ ,.4 COR . 2/5 FINAL 169 11490 Open 9/25/2001 169-11490 BL, Sepia I~ C vtú551 1-5 165 12012 Open 2/5/2002 i . 95EN/ NEU ~'^- l2 2/Q FINAL 3197 9950 - 7/27/2001 3197-9950 BL, Sepia i og í..MD Mudlog /;).'-l~ FINAL 199 11490 Case 8/2/2001 199-11490 Mudlog, Sepia .}t:óg ~ole Shear Sonic Imager 2/5 FINAL 3197 9950 Case 7/27/2001 3197-9950 BL, Sepia I l.eo C ví0204 FINAL 160 9950 Open 7/27/2001 160-9950, Digital Data ! RPf ær1d of Well Report FINAL Case 8/2/2001 End of Well Report, Paper - i Copy kD C V'1Ô332 FINAL 169 11490 Open 9/25/2001 169-11490 Digital Data I~ ND Mudlog I;;" '-'( 0 2 FINAL 199 11490 Case 8/2/2001 199-11490 Mudlog, Sepia I~ ~CDR 2/5 FINAL 169 11490 Open 9/25/2001 169-11490 BL, Sepia ~ ~ADN 2/5 FINAL 169 11490 Open 9/25/2001 169-11490 BL, Sepia I~ tØCPlot- DSI 2 FINAL 200 9950 Case 7/26/2001 200-9950 BL ~ 0 V'0234 FINAL 199 11490 Open 8/2/2001 199-11490 Digital Data I .é1i T .....-10234 199 11490 Open 8/2/2001 199-11490 ~ DN 2/5 FINAL 169 11490 Open 9/25/2001 169-11490 BL, Sepia ~ ~Repeat Formation Tester 2/5 FINAL 9677 9843 Case 7/27/2001 9677 -9843 BL, Sepia I~ 0 Mudlog Jr~ ~~ ~ 1 FINAL 199 11490 Case 8/2/2001 199-11490, Mudlog, Sepia ~ TVD Mudlog l:toöfj 1 FINAL 199 11490 Case 8/2/2001 199-11490, Mudlog, Sepia I DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2010860 Well Name/No. NORTHSTAR UNIT NS-13 MD 12000 T TVD 11261 Completion Date 12/2/2001 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y I&> Chips Received? ~ Analysis Received? ~ Interval Start Stop Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23017-00-00 Completion Status 1-01L Current Status 1-01L UIC N 160 - - I i -- J 9950 7/27/2001 160-9950 Sent Sample Set Number Comments Received ~--. Daily History Received? ~/N ~N Formation Tops Comments: ----- ----- --- -- - - --" Compliance Reviewed By: '\ k Date: 6 <.)~~ ]-~--- --- . /Vo'f- ~ ({ ~bMJ. V \< l \.1. 0""'" ~ 4. \I) I ,11 lU '- 1/\,1-- r, ... (VI J) V,' ...~~.... }}.t."'t~~., IN\\Ai.,.~ ìv'.b \.J~~~t~ ~u~å:.t~Î Mb Ûì &Í.t'.... ~l ,~~~v-~~ 'tV]) \l.. i ~Ifo,.,. \. ~ "'~ t- r ~.\ J '\-1' ~ 1 t\. b ~ t.,..,.-f ~~....l '1 \\ W'\r .tß'()1 M. D 'l2AA~Ò~'t-~~ t"ß I 41 .2. '2 ~ -- )...~ ~ \ Co \ S ~ - II cr 10)- <Cl ) ~ -It CU¡J- ~13ò - Il1(,j- L ~ ~ - - J À,o ò IJ I D 9..q.~ - J J g>q ~ 1\ ÀD ~ - 11 8')u <\~îl_cœ4> ~. r9l- u-~ ê~~~ ~ L, ~~ ( STATE OF ALASKA l ALASrv-\ OIL AND GAS CONSERVATION COMI\..-, SION REPORT OF SUNDRY WELL OPERATIONS 1. Ooerations Performed: Abandon 0 Alter CasingD Change Approved Program 0 SuspendC] Repair wellD Pull TubingD Operation Shutdown 0 Plug PerforationsD Perforate New PoolD PerforateD VarianceD Stimulate[!] Time ExtensionD Re-enter Suspended WellD Annular DisposalD OtherD 2. Operator BP Exploration (Alaska), Inc. Name: 4. Current Well Class: Development [XI ExploratoryD 5. Permit to Drill Number: 201-0860 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 StratigraphicD SeNiceD 9. Well Name and Number: NS-13 10. Field/Pool(s): Northstar 6. API Number 50-029-23017-00-00 7. KB Elevation (ft): 56.19 8. Property Designation: ADL-2799 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: I Northstar measured 12000 feet true vertical 11261 feet Plugs (measured) Junk (measured) measured 11910 feet true vertical 11 059 feet Length Size TVD Burst Collapse MD 3153 13-3/8" 68# L-80 44 - 3198 44 - 3178 4930 2270 10039 9-5/8" 47# L-80 44 - 10083 44 - 9350.4 6870 4760 699 4-1/2" 12.6# 13Cr80 11276 - 11975 10538.3 - 11235.9 8430 7500 1588 7" 26# L-80 9900 - 11488 9169.3 - 10749.8 7240 5410 Measured depth: 11724' - 11864' True vertical depth: 10985.41' -11125.14' 4-1/2" 12.6# 13Cr80 @ 40.051 -11269.86' Tubing: ( size, grade, and measured depth) Packers & SSSV (type & measured depth) ,-- 711 13Cr80 Packer @ 11221.861 /711 Liner Top Packer @ 9900" - 4-1/211 Liner Top Packer @ 11276.0T /4-1/211 HES HXO SSV @ 1996.961 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: 13 (See Attachment) Representative Daily Averaae Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 1,660 3,980 2 11,700 29,500 2 Tubing Pressure 710 1350 15. Well Class after proposed work: ExploratoryD DeyelopmentŒ] Service 0 16. Well Status after proposed work: Operational Shutdown D OilŒ] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or NIA if C.O. Exempt: 303-221 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 Signature Title Senior Petroleum Engineer Phone 564-4240 Date 9/26/03 ()D'~'~rl\ , - ny' ,;> \~ JI,~~ ~ (_I (5) I. Form 10-404 Revised 4/2003 ll:.';L::,','; I. i." ¡ -, ',,", ,:" l,.,),í ~~"}~\.Il)~' -"'" ( ( NS-13 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/20/03 Acid treatment, Pump pickle per procedure, 2 meth, 12 bbls 12% DAD Acid, 96 bbls SW, 63 bbls Diesel, flow back pickle to production. 08/21/03 Pickle flowback of 250 bbls, pump main DAD Acid treatment of, 67 bbls 12% Dad acid, 176 bbls SW displacement, 30 min soak, 233 bbls SW over-flush, 63 bbls Diesel for underbalance, shut in well for 4 hours. Turn well over to control room. FLUIDS PUMPED BBLS 2 Methonal 79 12% DAD Acid 505 Sea Water 126 Diesel 712 TOTAL Page 1 bp f .,. ..\I,.,,,. -..~~ ~.....- ~~- ~..- .....~ ~..... .'I'.~I\~ ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard p, O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 7, 2003 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS 13 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS13 well. This well has exhibited a high rate of decline and analysis of formation water indicates the formation of CaC03 scale is likely. Additionally, CaC03 scale has been recovered from this wellbore using slickline. The procedure includes the following major steps: /' . Pickle the tubing . Bullhead HCI based acid treatment (which includes scale inhibitor) . Flowback Sincerely, '7.J1¿A~~. ÞVl~ ) PIE Midhael J. CIS, P.E. . Senior Pe oleum Engineer BPXA, ACT, Northstar AUG ~~ 7 2003 ORIGINAl: 1. Type of Request: 0 Suspend 0 Operation Shutdown 0 Perforate 0 VarianceD Annuar Disposal 0 Abandon Alter CasinQ 0 Repair Well 0 PluQ Perforations 0 Stimulate IX) Time Extension 0 OtherD ChanQe Approved ProQram 0 Pull TubinQ 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development [XI ExploratoryD 201-0860 /' 3. Address: P.O. Box 196612 6. API Number .,/ Anchorage, Ak 99519-6612 Stratigraphic 0 Service 0 50-029-23017-00-00 7. KB Elevation (ft): 9. Well Name and Numbr RKB 56.19 NS13 8. Property Designation: 10. Field/Pool(s): ADL-312799 Northstar / Northstar 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): I Total Depth TVD (ft): IEffective Depth MD (It): IEffeCtiVe Depth TVD (It): Plugs (measured): runk (measured): 12000 11260.87 11910 11058.67 Casing Length Size MD TVD Burst Collapse top ft bottom top ft bottom Dsi Dsi Conductor Surface 3154 133/8" L-80 44 - 3198 44 - 3178 5020 2270 Intermediate 10037 9 5/8" L-80 44 - 10081 44 - 9348 6870 4760 Production 1588 7" L-80 9900 -11488 9169 - 10750 7240 5410 Liner 699 4 1/2" L-80 11276 - 11975 10538 -11236 8430 7500 Perforation Depth MD (ft): I Pertoralion Deplh TVD (It): Tubing Size: I Tubing Grade: Tubing MD (ft): 11724 - 11864 10985.4 - 11075.2 4.5" 12.6 Lb 13-Cr L-80 11269 Packers and SSSV Type: Packers and SSSV MD (ft): 7" Liner Top Packer/ 7" Bkr S-3 Perm Packer/ 9900/11222/11276/1997 4-1/2" Liner Top Packer/4-1/2" BBE SSV 12. Attachments: Description Summary of Proposalfj 13. Well Class after proposed work: Detailed Operations Program [~ BOP Sketch 0 Exploratory 0 DevelopmentŒ] Service 0 14. Estimated Date for '2/ ( 103 /' 15. Well Status after proposed work: Commencing Operation: Oil~ GasD PluggedD Abandoned D 16. Verbal Approval: Date: WAGD GINJD WINJD WDSPLD Commission Representative: Perpared by Garry Catron 564-4657 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Patty Hill Printed Name Patty Hill Title Production Engineer Signature l~.-v?' Phone 564-4346 Date 8/6/03 I~~ - Commission Use Only I SUndry~mb~¡: . . 1 Conditions of approval: Notify Commission so that a representative may witness ~. C.~.;;2;L.. Plug Integrity 0 BOP TestO Mechanciallntegrity TestO Location Clearance 0 Other: S~5~r;¡¡-~(0\ ij[þQ ~~ij~ 1 ~.~ if} 11:; '1 r,,' I, .' ~ ",.:~ì ,r,). r~, , ;' Subsequent Form Required: 404- ~D~\ BY ORDER OF sf~7 Approved by: COMMISIONER THE COMMISSION Date: U VJGI\- -9 /i ¡wcrs ~ STATE OF ALASKA ( Dv--J ¿X 1 ð 6 ALASKA Oil AND GAS CONSERVATION COMMISSION ~ 1jJ APPLICATION FOR SUNDRY APPROVAL' 20 AAC 25.280 Form 10-403 Revised 2/2003 ORIGINAL SUBMIT IN DUPLICATE ( ( Date: 02-05-2002 Transmittal Number:92395 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 LOQ Run Depth Bottom Depth LOQ Type NS13 06-24-2001 SCH 1-5 165 12000 VISION RESISTIVITY; TRUE VERTICAL DEPTH LOG; NS13 06-24-2001 SCH 1-5 165 12000 VISION RESISTIVITY; ~ MEASURED DEPTH LOG; 0 NS13 06-24-2001 SCH 3-5 131 12000 VISION DENSITY NEUTRON; -L. TRUE VERTICAL DEPTH LOG; C NS13 06-24-2001 SCH 3-5 131 12000 VISION DENSITY NEUTRON; ~ MEASURED DEPTH LOG; NS13 11-30-2001 SCH 1 11200 11850 PERFORATING RECORD; NS13 06-24-2001 SCH 1-5 165 12012 LDWG FORMAT; ARC5 OPENHOLE EDIT; (CD) ~~:J Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Buford Bates (Murphy Exploration (Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski RECEIVED FES 0 5 2002 Al88k. Oil & GasCons.ComßlI~n Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp ~".,.'..'.',,'.",.,..,',",',,';".,;",;,:"",!i,!!:~"",',',',',".",'"""','.,,.,,"""" ..-:' .i', .. \~, ~ ( f Date: 01-20-2002 Transmittal Number:92383 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If ou have an uestions, lease contact me in the PDC at 564-4091. Top SW Name Date Contractor Lo Run De th Bottom De th Lo T e NS13 11-29-2001 SCH 1 10940 11890 ULTRASONIC IMAGING TOOL; Úii:(!' - ~~:~5i¡,g::2":.;:-' ,I c7f.~,,; (1 QQ.9 p:J Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOaCC) Attn: Buford Bates (Murphy Exploration (Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski RECEIVED J,AJJ 2 J 2002 Alaska Oil & Gas Cons. Commission Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 b'p ...,,) ""':i'llifi\i..,. ,'.' " 'il:'," ¡','!'l' :~~'..'.. ",.. ' Ir"';~ ~ ( (' Date: 01-18-2002 Transmittal Number: 92381 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If ou have an uestions, lease contact me in the PDC at 564-4091. SW Name Date Media Title NS09 01-01-2002 COLOR LOGS (MUD); END OF WELL REPORT; HARDCOPY WELL DATA; NS13 07 -03-2001 COLOR LOGS (MUD); END OF WELL REPORT; ...0",' .. HARDCOPY WELL DATA; NS13 a 12-30-2001 HARDCOPY; ANADRILL DIRECTIONAL D ...O In SURVEY; &(~ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Buford Bates (Murphy Exploration (Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski RECEIVED J.t\N 1 [j 2002 AlllllaOl&GasCons. Commi8i0n And10rage 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 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well aa Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 'r¿{;!V;~,:h;:',-.- - 11_OC !1':l~oN$ 1169' NSL, 644'WEL, SEC. 11, T13N, R13E, UM : ,',:': I 'I. V~.ti>: At top of productive interval ~ ' ,'; 'DI ' ~ 1964' NSL 3796' WEL SEC. 11 T13N R13E UM ; .J.Z:.--:, . .._--- ~ h~~,~ .; At total d~pth ' , . . ~ VE~'" ..'.' ~ ~-" 10. Well Number 1984' NSL, 3806' WEL. SEC. 11. T13N. R13E. UM l..:::;:.10 ::.:: ~'.. j~~:"..~ ~ 11. Field and Pool 5. Elevation in feet (indicate KB. DF. etc.) 6. Lease Designation and Serial No. Northstar Unit KBE = 56.19' ADL 312799 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 16. No. of Completions 6-16-2001 11-20-2001 12-2-2001 39' MSL One 17. Total Depth (MO+ TVO) 118. Plug Back Depth (MO+ TVO) 119. Directional Survey 120. Depth where SSSV set I 21. Thickness of Permafrost 12000 11261 FTI 11910 11171 FTI aa Yes 0 No (Nipple) 1997' MOl 1545' (Approx.) 22. Type Electric or Other Logs Run GR, DIR, RES. DEN. NEU. USIT. PWD. ISONIC 23. CASING. LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" 169# X-56 Surface 161' 20" Driven 13-3/8" 68# L -80 44' 3198' 16" 1852 sx PF 'E', 470 sx Class 'G', 140 sx Ute 9-5/8" 47# L-80 44' 10083' 12-1/4" 03 sx Econolite, 68 sx Lite, 400sx Class 'G' 7" 26# L-80 9920' 11488' 8-1/2" 318 sx Class 'G' 4-1/2" 12.6# 13Cr 11276' 11975' 6-1/8" 97 sx Class 'G' Classification of Service Well 7. Permit Number 201-086 301-312 8. API Number 50- 029-23017-00 9. Unit or Lease Name Northstar Unit NS13 AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval. size and number) 2-7/8" Gun Diameter. 6 spf MD TVD 11724' -11864' 10985'-11125' 25. SIZE 4-1/2",12.6#, 13CrVam Ace TUSING RECORD DEPTH SET (MD) 11270' PACKER SET (MD) 11222' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE. ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 270 Bbl's Diesel 27. Date First Production December 8. 2001 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing. gas lift, etc.) Flowing PRODUCTION FOR OIL-BsL TEST PERIOD GAs-McF WATER-BsL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BsL GAs-McF WATER-BsL CHOKE SIZE 1 GAS-OIL RATIO OIL GRAVITy-API (CORR) 28. CORE DATA Brief description of lithology. porosity, fractures. apparent dips and presence of oil, gas or water. suReeEtVt:u ~IAN 0 9 20!lZ Alaska Oil & Gas Coos. Commission Anchorage Form 10-407 Rev. 07-01-80 0 RIG I NA LRBOMS BFl JANjj. a&UbmitlnDUPI~~ I' ( (" 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top of Kuparuk 9480' 8759' Top of Kuparuk 'C' 9669' 8943' Top of Miluveach 9992' 9260' Top of Sag River 11462' 10724' Top of Shublik 11554' 10816' Top of Ivishak 11634' 10896' RECE\VED H\N 0 9 2002 \.. I. . &Sion A\as\<a Oil & Gas coos. comrm Anchorage 31 . List of Attachments: Summary of Daily Drilling Reports, Surveys and Leak-off Test Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date 01- DC:¡ .0 NS13 Well Number 201-086 301-312 Permit No. / A roval No. Prepared By Name/Number: Sondra Stewman, 564-4750 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 ORIGINAL (' ( BP EXPLORATION Page 1 of14 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: 7/9/2001 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 6/14/2001 00:00 - 21 :00 21.00 Rig Released from NS-27 at 2100 hrs 6/14/01. 21 :00 - 00:00 3.00 MOB P PRE Moving rig from NS-27 to NS-13. 6/15/2001 00:00 - 05:00 5.00 MOB P PRE Finish moving rig from NS-27 to NS-13. Accept rig at 0500 hrs 6/15/01. 05:00 - 17:00 12.00 RIGU P PRE RIU supply lines between pipe rack and rig. Test G&I injection line to 4500 psi. OK. Charge supply lines with fluids into rig. Mix spud mud. Build berms around rig and service complex. Start N/U Hydril on diverter spools. Spot and RIU Schlumberger wireline unit and sheaves to run gyro. Spot rig mats and build ramp for forklift to put tools on pipe shed elevator. 17:00 - 18:00 1.00 RIGU P PRE Hold pre-spud meeting with Nabors night crew and service companies. 18:00 - 19:00 1.00 RIGU P PRE Hold pre-spud meeting with Nabors day crew. 19:00 - 22:00 3.00 RIGU P PRE Finish R/U riser between Hydril and flowline. Install and tighten turnbuckles on Hydril. Install mousehole. Finish RIU rig floor to P/U BHA. 22:00 - 23:00 1.00 RIGU P PRE Bring mise BHA X-O's and tools to rig floor. 23:00 - 00:00 1.00 RIGU P PRE P/U 13 3/8" hanger and drift through the Hydril and riser spools. RKB = 44.40' 6/16/2001 00:00 - 01 :00 1.00 DRILL P SURF BHA #1 - M/U 16" bit, X-O, stab, and 1 drill collar, and 1 stand of HWDP and GIH. 01 :00 - 02:00 1.00 DRILL P SURF Install derrick safety bar. This bar keeps the tugger lines from getting into the derrick board fingers. 02:00 - 03:00 1.00 DRILL P SURF Hang Schlumberger wireline sheaves for gyro. 03:00 - 04:00 1.00 DRILL P SURF Break circulation and pump through surface equipment and check for leaks. OK. 04:00 - 04:30 0.50 DRILL P SURF GIH and tag ice plug at 55' RKB. Drill through ice plug 10'-15' thick. POOH to HWDP. 04:30 - 07:00 2.50 DRILL P SURF BHA #1 - Continue P/U remaining drill collars and jars, GIH with HWDP. Tag up on gravel at 156' RKB. Wash down to 229'. Circulate out. Gyro at 100' 0.7 degrees Azimuth 143 150' 1.2 degrees Azimuth 145 200' 1.3 degrees Azimuth 140 05:30 - 07:00 1.50 DRILL P SURF Wash down from 156' to 229'. Circulate out. 07:00 - 11 :00 4.00 DRILL P SURF POOH with HWDP. M/U BHA #2 which includes orienting sub, MWD, and jars. 11 :00 - 11 :30 0.50 DRILL P SURF Drill to -400'. 11 :30 - 00:00 12.50 DRILL P SURF Run gyro and MWD survey. Gyro - 270' 0.4 degrees Azimuth 145.8 MWD - 297' 0.24 degrees Drill ahead to 1105'. Discuss with Office. Decision made to drill ahead without gyro Printed: 12/4/2001 9:39:01 AM ( ( BP EXPLORATION Page 2 of 14 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: 7/9/2001 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 6/16/2001 11 :30 - 00:00 12.50 DRILL P SURF surveys from 371' until the MWD tool was free of magnetic interference (NS-10) at 1104'. This decision also included not surveying the section from 371' to 1104' with the gyro if the inclination stayed below 0.5 degrees until surface hole TD. The inclination in this section stayed below 0.2 degrees, so no gyro was run at 1104', and the azimuths were interpolated from the erroneous MWD azimuthal measurements. The max error in the bottom hole location using best-guess azimuths at 1104' is 5.1'. This was considered acceptable. The unknown azimuths for this interval will be measured at the surface hole TO by dropping a gyro. This gyro run at TO will also be used to qualify the MWD tool for JORPS. 6/17/2001 00:01 - 17:00 16.98 DRILL P SURF Drill from 1105' to 2824'. 17:00 - 18:00 1.00 DRILL P SURF Starting to see some fill on bottom. Pick up off bottom and circulate high vis sweep around. 18:00 - 00:00 6.00 DRILL P SURF Drill from 2824' to 3165'. ART 11.0 hours AST 3.9 hours 6/18/2001 00:00 - 01 :00 1.00 DRILL P SURF Finish drilling to 3215' MD TO. 01 :00 - 03:00 2.00 DRILL P SURF Pump high vis sweep and circulate out. 03:00 - 05:30 2.50 DRILL P SURF Round trip wiper trip to HWDP. One tight spot at 3108'. Max pull 30k over P/U. Work thru without top drive. GIH slick. No problems. No fill on bottom. 05:30 - 07:30 2.00 DRILL P SURF Circulate 2 bottoms up. Drop gyro and pump down slowly. Pump slug. 07:30 - 09:30 2.00 DRILL P SURF POOH to BHA. Hole slick. No problems. 09:30 - 12:00 2.50 DRILL P SURF Rack back BHA in anticipation of drilling NS-14 surface hole. Clean rig floor area. 12:00 - 13:00 1.00 CASE P SURF M/U 133/8" casing hanger to landing joint section. UD hanger joint and hanger back in the pipe shed. 13:00 - 14:30 1.50 CASE P SURF RIU casing running tools. 14:30 - 15:30 1.00 CASE P SURF Pre-job on running 13 3/8" casing. Perform a top drive and derrick visual inspection for loose bolt, pins, etc. No problems discovered. 15:30 - 21 :30 6,00 CASE P SURF Run a total of 79 jts 13 3/8" 68# L-80 BTC. FIS 3197.53' FIC 3155.41' UC 3112.94' ES Cementer 1608.28 Hole slick. No problems. 21 :30 - 22:00 0.50 CASE P SURF M/U hanger and two piece landing joints. SIO and land hanger. Final PIU 275k (includes 65k for top drive) Final SIO 220k (includes 65k for top drive) 22:00 - 00:00 2.00 CASE N SURF Back out casing fill-up tool from top drive. The casing fill-up tool was resting on the tool push plate on the top of the casing collar. At 2215 hrs a Floorhand was screwing a lifting eye into the top of the fill-up tool. During the operation an injury occured. The Injured employee was taken to the Northstar Medic. All drilling related activities were temporarily suspeneded pending further evaluation. 6/19/2001 00:00 - 01 :00 1.00 CASE N MISC SURF Finish accident review and hold PJSM for RID casing fill-up tool Printed: 12/4/2001 9:39:01 AM ( (' BP EXPLORATION Page 3 of 14 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: 7/9/2001 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 6/19/2001 00:00 - 01 :00 1.00 CASE N MISC SURF and RlU cement head. 01 :00 - 01 :30 0.50 CEMT P SURF UD fill-up tool. RID Halliburton cementing head and cementing hose. 01 :30 - 04:30 3.00 CEMT P SURF Circulate and condition mud prior to cementing. 04:30 - 07:00 2.50 CEMT P SURF Pump 1 st stage cement job LEAD - Type L, 140 sks, 103 bbls, Wt 10.5, Yield 4.15 TAIL - Premium G, 2% CaCI, 470 sks, 96 bbls, Wt 15.9, Yield 1.15 Displacement 25 Seawater 441.3 bbls mud at 10 bpm with full returns. Bump plug. BPV's OK. Open ES cementer at 2200 psi 07:00 - 08:30 1.50 CEMT P SURF Circulate and condition mud between cement stages. Got-5 bbls from 1 st stage cement job after opening the ES cementer. 08:30 - 12:00 3.50 CEMT P SURF Pump 2nd stage cement TAIL - Permafrost E, 1853 sks, 716 bbls, Wt 12.0, Yield 2.17 Displacement 25 bbls seawater 215.9 bbls mud at 8 bpm with full returns Bump plug Close ES cementer with 1600 psi Check BPV's - OK 12:00 - 13:30 1.50 DRILL C SURF Develope procedure for RID Halliburton cementing head. 13:30 - 14:00 0.50 DRILL P SURF RID Halliburton cementing head. 14:00 - 15:00 1.00 DRILL C SURF Develope procedure for UD landing joint. 15:00 - 15:30 0.50 DRILL C SURF Hold planning meeting with all Drilling personnel concerning the revised forward plan from Anchorage office. 15:30 - 16:30 1.00 DRILL P SURF UD landing joint. Clear rig floor area. 16:30 - 17:30 1.00 DRILL P SURF Change from long to short bails. Change to drill pipe elevators. 17:30 - 19:30 2.00 DRILL P SURF PIU wash joint on drill pipe and wash out BOPS. 19:30 - 23:00 3.50 DRILL C SURF Show I orient new rig crew personnel around the rig while the investigation team conducted interviews. 23:00 - 00:00 1.00 DRILL P SURF UD 16" BHA tools and MWD. 6/20/2001 00:00 - 01 :00 1.00 DRILL P INT1 PJSM Walk around with new personnel. 01 :00 - 02:30 1.50 DRILL P INT1 Lay down BHA from 16" hole. 02:30 - 03:00 0.50 DRILL P INT1 PJSM 03:00 - 04:30 1.50 DRILL P INT1 Nipple down riser & diverter and set on NS-14. 04:30 - 05:30 1.00 DRILL P INT1 Nipple up tubing head adaptor. 05:30 - 10:00 4.50 DRILL P INT1 Nipple up BOP - Install choke & killlines, turnbuckles, Koomey hoses. Install drilling sweep & valve. Function rams. 10:00 -11:00 1.00 DRILL P INT1 Install master bushings & iron roughneck track. Grease choke valve manifold & clean rig floor. 11 :00 - 11 :30 0.50 DRILL P INT1 PJSM 11 :30 - 12:00 0.50 DRILL P INT1 Install test plug & fill lines. 12:00 - 14:30 2.50 DRILL N WAIT INT1 UA test rig crews. 14:30 - 15:00 0.50 DRILL P INT1 PJSM for testing BOP. Low to 250 psi for 5 min. & high to 5,000 psi for 10 min. 15:00 - 16:30 1.50 DRILL N SFAL INT1 Detected leaks. PJSM - Tighten stack, choke unibolts, packijng gland nuts on lockdown screws. Grease HCR kill line. Printed: 12/4/2001 9:39:01 AM (' ( BP EXPLORATION Page 4 of 14 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: 7/9/2001 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 6/20/2001 16:30 - 22:00 5.50 DRILL P INT1 Continue with BOP test. AOGCC Rep. Jeff Jones waived witness of the test. 22:00 - 22:30 0.50 DRILL P INT1 PJSM- Pull test plug & install wear ring. 22:30 - 23:00 0.50 DRILL P INT1 Back out test joint and Lay down. Blow down mud lines & top drive. 23:00 - 00:00 1.00 DRILL P INT1 PJSM - Service top drive 6/21/2001 00:00 - 01 :00 1.00 DRILL P INT1 Service top drive & install mousehole. 01 :00 - 01 :30 0.50 DRILL P INT1 PJSM for making up BHA. 01 :30 - 03:30 2.00 DRILL P INT1 M/U BHA # 3 - Orient MWD & Motor. 03:30 - 04:30 1.00 DRILL P INT1 RIH 04:30 - 05:00 0.50 DRILL P INT1 Wash down & tag ES cementer at 1608'. 05:00 - 05:30 0.50 DRILL P INT1 PJSM - Test casing to 1000 psi & hold for 5 min. 05:30 - 06:00 0.50 DRILL P INT1 Drill Out ES Cementer Note: PJSM -- Test Csg to 1000 psi for 5 minutes. 06:00 - 06:30 0.50 DRILL P INT1 RIH to cement above the landing collar. Note: Hit tight spot @ 2015' -- necessary to wash and rotate to get past this spot. 06:30 - 08:00 1.50 DRILL P INT1 Wash down to 3166' to top of cement. Circulate MWin = MWout = 9.2 ppg 08:00 - 09:00 1.00 DRILL P INT1 Test Casing to 2500 psi for 30 minutes -- Good Test. Note: Reviewed 01, 02 and D5 Drills with Rig Crews. 09:00 - 10:00 1.00 DRILL P INT1 Perform 05 Drill with Rig Crew -- BID Choke and Kill Lines. 10:00 - 14:00 4.00 DRILL P INT1 Drill Cement and Float Track (LC,FC and FS) plus 30' of new formation to 3245' md. Note: Return mud was seriously clabbored up from cement contamination. Difference is sea water clorides are 2K vs. 19k normally -- probably Kuparuk River freshwater overrun. 14:00 - 14:30 0.50 DRILL P INT1 Circulate hole clean until MWin = MWout = 8.7 ppg. 14:30 - 16:00 1.50 DRILL P INT1 Perfom FIT -- 12.5 ppg EMW. Blow down choke and kill lines. 16:00 - 17:30 1.50 DRILL P INT1 PJSM -- Displace well to new drilling fluid. 17:30 - 00:00 6.50 DRILL P INT1 Drilling ahead while building from 21 degree to 30 degree to planned tangent. 6/22/2001 00:00 - 07:30 7.50 DRILL P INT1 Drlg fl 3593' to 4256' md. Note: Finished build at 3611' md. 07:30 - 08:30 1.00 DRILL P INT1 Circulate Hi Vis Sweep and monitor well -- Static. 08:30 - 10:00 1.50 DRILL P INT1 Perform short trip to 13-3/8" casing shoe @ 3196' md. Note: 1) Stands 1 thru 4 pulled with no problems. 2) Stands 5 and 6 overpull 30k. 3) Stand 7 pulled 45K over and swab, wiped stand and eliminated swabbing. 4) Finished pulling stands 8-11 with no problem. 10:00 - 12:00 2.00 DRILL P INT1 Drlg f/4256' to 4510' md. 12:00 - 00:00 12.00 DRILL P INT1 Drlg fl 4510' to 5116' md. Note: Sliding 30' every 400' to arrest a 1/3 deg/1 00' dropping tendency and a 1/2 deg/100' walking tendency to left. 6/23/2001 00:00 - 01 :00 1.00 DRILL P INT1 Drlg fl 5116' -- 5209' md. Note: Pumped Hi-Vis Sweep at middle of stand down. 01 :00 - 01 :30 0.50 DRILL P INT1 Finish Circulating Hi-Vis Sweep -- monitor well -- Static. 01 :30 - 03:00 1.50 DRILL P INT1 Perform Wiper Trip. Note: Maximum Drag 25K, Avg Drag 5-10, Hole Fill Good. Printed: 12/4/2001 9:39:01 AM < ( BP EXPLORATION Page 5 of 14 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: 7/9/2001 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 6/23/2001 03:00 - 12:00 9.00 DRILL P INT1 Drlg fl 5209' -- 5781' md. 12:00 - 00:00 12.00 DRILL P INT1 Drlg fl 5781' -- 6327' md. Note: Still sliding 25' per 500' drilled to arrest slight dropping and walking tendency. 6/24/2001 00:00 - 03:00 3.00 DRILL P INT1 Drlg. from 6327' to 6442' MD. 03:00 - 03:30 0.50 DRILL P INT1 Circulate - monitor well - pump slug. 03:30 - 06:30 3.00 DRILL P INT1 POOH. Hole slick. No problems. 06:30 - 07:00 0.50 DRILL P INT1 PJSM for LD BHA. 07:00 - 08:00 1.00 DRILL P INT1 UD BHA#3. 08:00 - 08:30 0.50 DRILL P INT1 Download COR & clean rig floor. 08:30 - 10:30 2.00 DRILL P INT1 PIU BHA # 4. Orient MWD & motor. Change bend on motor from 1.5 deg. to 1.15 deg. 10:30 - 11 :00 0.50 DRILL P INT1 Shallow test MWD & PJSM for PU ADN and source. 11 :00 - 12:00 1.00 DRILL P INT1 PIU ADN and load source. 12:00 - 14:00 2.00 DRILL P INT1 RIH with HWDP & 5" drill pipe. 14:00 - 15:00 1.00 DRILL P INT1 PJSM for cut & slip drilling line and man riding on tugger operation. 15:00 - 17:00 2.00 DRILL P INT1 Cut and slip 102' of drilling line. Inspect brakes & drawworks. 17:00 - 18:30 1.50 DRILL P INT1 PJSM - Service top drive & crown. 18:30 - 20:00 1.50 DRILL P INT1 RIH from 3140' to 6370'. Hole slick. No problems. 20:00 - 20:30 0.50 DRILL P INT1 Wash down from 6370' to 6442'. 20:30 - 00:00 3.50 DRILL P INT1 Drill and slide from 6442' to 6661'. 6/25/2001 00:00 - 00:00 24.00 DRILL P INT1 Drill from 6661' to 8800'. No hole problems. Planned depth for angle drop was 8750'. At 7850 allowed angle to start dropping while rotating and without sliding. This saved a good deal of sliding time. 6/26/2001 00:00 - 06:30 6.50 DRILL P INT1 Drill from 8800' to 9400'. 06:30 - 08:00 1.50 DRILL P INT1 Circulate bottoms up & monitor well. Pump slug. 08:00 - 10:30 2.50 DRILL P INT1 POH from 9400' to 6300'. Five intermittment tight spots from 7200' to 6450'. Able to work through without backreaming. 10:30 - 12:00 1.50 DRILL P INT1 RIH to 9328. Wash to bottom. No hole problems. 12:00 - 13:00 1.00 DRILL P INT1 Drill from 9400' to 9423'. 13:00 - 13:30 0.50 DRILL P INT1 Circulate out 6,000 units of gas. 13:30 - 00:00 10.50 DRILL P INT1 Drill from 9423' to 9725'. 6/27/2001 00:00 - 10:30 10.50 DRILL P INT1 Drill from 9725' to TD @ 10104' MD. 10:30 - 12:30 2.00 DRILL P INT1 Circulate hole clean. 12:30 - 13:00 0.50 DRILL P INT1 Monitor well & POH with 3 stands. Monitor well. 13:00 - 18:00 5.00 DRILL P INT1 Pump dry job & blow down all lines. POH to shoe. 18:00 - 18:30 0.50 DRILL P INT1 Monitor well & perform 0-1 drill. 18:30 - 20:00 1.50 DRILL P INT1 Continue POH. PJSM for laying down BHA. 20:00 - 21 :30 1.50 DRILL P INT1 PJSM- Lay down source & ADN. 21 :30 - 00:00 2.50 DRILL P INT1 Lay down BHA # 4. 6/28/2001 00:00 - 01 :00 1.00 DRILL P INT1 UD tools. Clean rig floor. 01 :00 - 01 :30 0.50 EVAL P INT1 PJSM for rigging up Schlumberger. 01 :30 - 02:30 1.00 EVAL P INT1 RIU wireline and Logging tools. Printed: 12/4/2001 9:39:01 AM (" (' BP EXPLORATION Operations Summary Report Page 6 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS13 NS13 DRILL +COMPLETE NABORS NABORS 33E Start: 6/14/2001 Rig Release: 7/9/2001 Rig Number: 33E Spud Date: 6/16/2001 End: Date From - To Hours Activity Code NPT Phase Description of Operations 6/28/2001 02:30 - 05:00 2.50 EVAL P INT1 RIH with PEX tool. Would not go past 5945'. Made four attempts. Landed at same depth. No problem picking up. 05:00 - 06:00 1.00 EVAL N INT1 POH. Install longer rubber extension on end of tool. Change three bottom standoffs from 9" to 6". 06:00 - 13:30 7.50 EVAL P INT1 RIH with PEX tool. Log from 9950' to 1400'. POH. 13:30 - 23:30 10.00 EVAL P INT1 RlU RFT, log #2. Took 22 pressure samples from 9843' to 9677'. Took two fluid samples at 9683' and 9761'. POH. RID Schlumberger. 23:30 - 00:00 0.50 BOPSUF N HMAN INn Prepare to test BOPs. RlU to drain stack through casing valve with rig 3" air pump. (Unable to drain into cellar because cellar needs to be resealed with impermeable coating.) Had leak between G&I and rig. Valve to drag chain in shaker room was plugged and a valve to the G&I was open but a valve inside the G&I was closed, pressuring the line between the rig and G&I. All hoses and clamps were in good condition. Rig had small amount of mud spray. Rig crew started cleaning spray on walls. ACS rep stated leak amounted to 40 gallons which included the water to clean the mud spray from the rig wall. Leak was called a 40 gallon non-process leak. All fluid was cleaned up and disposed of in G&I. 6/29/2001 00:00 - 00:30 0.50 BOPSUR P INT1 PJSM on Testing BOPs 00:30 - 01 :30 1.00 BOPSUR P INT1 Pull wear ring and install test plug 01 :30 - 02:30 1.00 BOPSUF P INT1 RIU to test BOPs. 02:30 - 10:30 8.00 BOPSUF P INT1 Test BOPs and choke manifold as per BP policy. 10:30 - 11 :30 1.00 BOPSUF P INT1 RID test equipment and blow down choke and kill line. 11 :30 - 12:30 1.00 BOPSUF P INT1 Service Top Drive 12:30 - 13:30 1.00 EVAL P INn M/U BHA 13:30 - 17:30 4.00 EVAL P INn RIH. Fill DP every 3,000'. RIH. Tagged at 9926. 17:30 - 18:30 1.00 EVAL P INn Wash and ream to bottom. After 9926 took weight 4 times while reaming to bottom. No drag picking up. 18:30 - 21 :00 2.50 EVAL P INT1 Circulate B/U and condition mud. 21 :00 - 00:00 3.00 EVAL P INT1 Monitor well. POH 2 stands. Pump dry job. POH. 6/30/2001 00:00 - 02:00 2.00 EVAL P INT1 Continue POOH to 13-3/8" casing shoe. 02:00 - 03:00 1.00 EVAL P INT1 Monitor well and continue to POOH. 03:00 - 03:30 0.50 EVAL P INn Montior well and POOH with HWDP. 03:30 - 04:00 0.50 DRILL P INn PJSM -- LD BHA #5. 04:00 - 04:30 0.50 CASE P INT1 Clear rig floor. 04:30 - 06:00 1.50 CASE P INT1 PJSM -- Pump out stack with trash pump. Pull Wear Ring and Install test plug. 06:00 - 07:30 1.50 CASE P INT1 Change top set of pipe rams to 9-5/8" and test bonnet seals to 1000 psi. Pull test plug. 07:30 - 09:30 2.00 CASE P INn PJSM -- Rig up to run 9-5/8" intermediate casing. 09:30 - 00:00 14.50 CASE P INn PJSM -- Run 9-5/8" 240 joints of 9-5/8" casing. Notes: 1) 2 joints and landing joint left to run. 2) Hole started taking fluid while running last 25 stands -- slowed running speed to reduce losses. 3) No significant problems noted to this point -- hole in excellent condition. 7/1/2001 00:00 - 02:00 2.00 CASE P INT1 Run 9 5/8, 47#, L-80 casing. RlU Landing joint and hanger. Break circulation. Shut down pump. Land casing. Set at 10083' MD. Printed: 12/4/2001 9:39:01 AM (' ( BP EXPLORATION Page 7 of 14 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: 7/9/2001 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 7/1/2001 02:00 - 04:30 2.50 CASE P INT1 RIU cement head. Circulate capacity of casing. Had PJSM for cementing casing. Established circulation at 1 BPM and increased to 10 BPM. 04:30 - 08:30 4.00 CEMT P INT1 Mix and pump cement as per program. See cement report. Displaced cement with mud pumps. Pumped calculated strokes (96%) efficiency plus 1/2 shoe track (8392 strokes). Plug did not bump. HOWCO flow meter showed 2 bbls difference from rig pumps. Check floats. OK 08:30 - 10:30 2.00 CASE P INT1 RID landing joint, cement equipment, tongs, change bails and drain stack. 10:30 - 12:00 1.50 CASE P INT1 Install 9 5/8 packoff. Test to 5,000 PSI 12:00 - 12:30 0.50 CASE P INT1 Rig down packoff running tool. 12:30 - 14:00 1.50 CASE P INT1 RIU lines to bullhead mud down 9 5/8 X 13 3/8 Annulus to flush annulus. 14:00 - 19:30 5.50 CASE P INT1 Pumped 192 bbls of 9.8 mud out of critical path. Remove 9 5/8 rams. Install VB rams. Test to 5,000 PSI. 19:30 - 22:00 2.50 CASE P INT1 Slip and cut 100' of drlg line. Service top drive and rig. 22:00 - 00:00 2.00 CASE P INT1 Lay down 8" BHA. 7/2/2001 00:00 - 01 :00 1.00 CASE P INT1 Finish LID BHA. 01 :00 - 04:00 3.00 CASE P INT1 M/U BHA # 6. 04:00 - 07:30 3.50 CASE P INT1 RIH to 9814'. Tagged cement. 07:30 - 08:00 0.50 CASE P INT1 Circulate and condition mud. 08:00 - 09:00 1.00 EVAL P INT1 Test casing to 3000 PSI. for 30 minutes. 09:00 - 09:30 0.50 EVAL P INT1 Conduct D-5 drill. 09:30 - 11 :00 1.50 EVAL P INT1 Drill cement from 9814' to Float collar at 9997'. Test casing to 3000' for 10 minutes. 11 :00 - 12:30 1.50 DRILL P INT2 Drill out float equipment, cement and 20' of new hole to 10124'. 12:30 - 13:00 0.50 DRILL P INT2 Circulate and condition mud for LOT. 13:00 - 13:30 0.50 DRILL P INT2 Conduct LOT to 15.0 ppg EMW with 9.8 ppg mud. 13:30 - 17:30 4.00 DRILL P INT2 Circulate and condition mud. Raise mud weight to 11.3 ppg. 17:30 - 20:30 3.00 DRILL P INT2 Drill from 10124' to 10295'. 20:30 - 21 :30 1.00 DRILL N INT2 Repair #2 mud pump. 21 :30 - 00:00 2.50 DRILL P INT2 Drill from 10295' from 10411'. No hole problems. 7/3/2001 00:00 - 15:00 15.00 DRILL P INT2 Drill from 10411 to TD at 11490'. 15:00 - 16:30 1.50 DRILL P INT2 Criculate and Condition mud. 16:30 - 19:00 2.50 DRILL P INT1 Short trip to 9 5/8 shoe. No hole problems. 19:00 - 20:00 1.00 DRILL P INT2 Circulate BU for POH 20:00 - 00:00 4.00 DRILL P INT2 POH to 9 5/8 shoe. Drop rabbit. Pump dry job. Continue POH. 7/4/2001 00:00 - 03:00 3.00 DRILL P INT2 POH. 03:00 - 03:30 0.50 DRILL P INT2 PJSM for laying down BHA. 03:30 - 06:30 3.00 DRILL P INT2 LD BHA #6. 06:30 - 07:30 1.00 CASE P INT2 Rig up to run 7" liner. 07:30 - 08:00 0.50 CASE P INT2 PJSM for running 7" liner. 08:00 - 11 :00 3.00 CASE P INT2 Ran 39 joints of 7", 26#, L-80, Modified BTC liner. 11 :00 - 11 :30 0.50 CASE P INT2 Make up HMC liner hanger and ZXP liner packer. Liner set at 11488'. Top of liner at 9900'. 11 :30 - 12:00 0.50 CASE P INT2 Make up one stand of DP and circulate 1.5 times liner volume. 12:00 - 19:00 7.00 CASE P INT2 RIH with 7" liner on 5" DP to 9 5/8 shoe. 19:00 - 20:00 1.00 CASE P INT2 Make up Baker Cement head and set back on skate 20:00 - 21 :30 1.50 CASE P INT2 RIH with 7" liner on 5" DP to TD at 11490'. 21 :30 - 23:00 1.50 CASE P INT2 PU Baker cement head. Circulate and condition mud. Pumped 1 1/2 string volumes-- 375 bbls. Held PJSM for cementing liner. Printed: 12/4/2001 9:39:01 AM (' ( BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: 7/9/2001 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 7/4/2001 23:00 - 00:00 1.00 CEMT P INT2 Begin cement job for 7' liner. 7/5/2001 00:00 - 01 :00 1.00 DRILL P INT2 Cemented liner as per program. See cement report. Displaced cement with rig pumps. Liner displaced with 9.7 ppb brine. 11.3 ppb mud above liner in 9 5/8 casing. Bumped plug. Pressured to 3500 psi and set hanger. Checked floats. 01 :00 - 02:00 1.00 DRILL P INT2 Set packer and released from liner. Circulate BU. Had 5 bbls of cement returns. 02:00 - 03:00 1.00 DRILL P INT2 Test liner top to 15 ppg EMW plus 500 psi. Pressured to 2400 psi with 11.1 ppg mud. Held for 30 minutes. 03:00 - 05:00 2.00 DRILL P INT2 Reverse circulate above liner top and displace with high vis pill and 9.7 ppg brine. 05:00 - 07:30 2.50 DRILL P INT2 Rig down reverse lines. RID cement head and lay down same. 07:30 - 10:30 3.00 EVAL P INT2 POH with DP and setting tool. 10:30 - 16:00 5.50 EVAL P INT2 Made decision to break all connections and re-dope connections prior to cold stacking rig. Continued POH. 16:00 - 00:00 8.00 EVAL P INT2 RIH with stands from derrick. POH. Break and re-dope all connections. 7/6/2001 00:00 - 05:00 5.00 DRILL P INT2 POH with DP. Break and re-dope all connections. 05:00 - 06:00 1.00 DRILL P INT2 Pump diesel in top 100' of 9 5/8 06:00 - 07:00 1.00 DRILL P INT2 Clean rig. Pull wear ring. Found damaged threads in TWC profile in Tubing Hanger. Attempt to repair on location. 07:00 - 07:30 0.50 DRILL P INT2 PJSM on changing rams. 07:30 - 09:30 2.00 DRILL P INT2 Change top set of pipe rams to 2 3/8. 09:30 - 12:00 2.50 DRILL P INT2 Send tubing hanger to Baker in Deadhorse for repair. Service top drive. Change out saver sub on Top Drive to 2 3/8. 12:00 - 16:30 4.50 DRILL N INT2 Wait on tubing hanger. Load pipe shed with 13318 casing in preparation for cold stacking. 16:30 - 18:30 2.00 DRILL P INT2 Install tubing hanger and test to 5000 PSI 18:30 - 19:30 1.00 DRILL P INT2 Remove bottom 5" rams and install 2 3/8 rams 19:30 - 00:00 4.50 DRILL P INT2 Nipple down BOPs 11/17/2001 00:00 - 10:30 10.50 DRILL P INT2 CONTINUE MIXING 9.3 # DRILL IN MUD- 1500 BBLS. NU DRILLING RISER AND MOUSE HOLE. CONTINUE WELDING OPERATIONS: PIPE ELEVATOR, TRIP TANK, AND BOPE RACK. INSTALL MULE LINE SHEAVE BRACKETT. REMOVE CAMERA MOUNT DERRICK. UNLOAD 41/2" VAM ACE TUBING TO MAKE ROOM FOR 4" DP IN PIPE SHED. 10:30 - 11 :45 1.25 BOPSUF P INT2 AOGCC REP CHUCK SCHEVE ON HAND TO WITNESS BOPE TEST. RU AND PRESSURE TEST CHOKE MANIFOLD TO 300/5000 PSIG. TEST CHOKE MANIFOLD ON CRITICAL PATH WHILE INSTALLING SHEAR RAMS. 11 :45 - 12:15 0.50 BOPSUF P INT2 PRE SPUD SAFETY MEETING WITH BOTH RIG CREWS. 12:15 -14:00 1.75 BOPSUF P INT2 CONTINUE WITH PRESSURE TEST ON CHOKE MANIFOLD. 14:00 - 16:00 2.00 BOPSUF P INT2 PULL TWC. MU LANDING JT. BOLDS. PULL TUBING HANGER AND PUP JT. LD TUBING HANGER. 16:00 - 17:00 1.00 BOPSUF P INT2 RUN TEST PLUG. RUN IN 4 LOS. 17:00 - 00:00 7.00 BOPSUF P INT2 TEST BOPE STACK. TROUBLE SHOOT LEAKS AT DOORS AND GATES. (CONSEQUENCE OF STACK REBUILD). ONGOING WELDING WORK FOR TRIP TANK. CONINUE MIXING MUD AND PREPPING PIPE SHED FOR 4" DRILLPIPE. 11/18/2001 00:00 - 01 :00 1.00 BOPSUF P INT2 Continue to test BOPE . Chuck Sheve witness. 01 :00 - 01 :30 0.50 BOPSUF P INT2 Pull Test Plug and install Wear Ring. Printed: 12/4/2001 9:39:01 AM (' ( BP EXPLORATION Page 9 of 14 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: 7/9/2001 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 11118/2001 01 :30 - 02:00 0.50 CASE P INT2 Prepare to test kill Line 02:00 - 04:30 2.50 CASE N SFAL INT2 Thaw Frozen Kill Line- RIU to Test pump and Choke Line. 04:30 - 05:30 1.00 CASE P INT2 Test Casing down Choke Manifold with Test Pump to 4200 psil 30 minutes. 05:30 - 07:00 1.50 DRILL P INT2 PJSM. Pump out 7 bbls Diesel from stack to Bleed Tank. ACS disposed of diesel. 07:00 - 08:00 1.00 DRILL P INT2 Attempt rig shut down. No Go. Unable to shut down rig. 08:00 - 10:30 2.50 DRILL P INT2 Make up 6.1/8" Bit and Triple Combo LWD tools. Load Nuclear Source. 10:30 - 15:30 5.00 DRILL P INT2 Single In 4" HWDP- new pipe. Make and break each connection. Change elevators. Attempt ESD again. 15:30 - 16:30 1.00 DRILL P INT2 Line up to pump- conduct shallow test on LWD tools- good. 16:30 - 17:30 1.00 DRILL P INT2 Switch rig to Hi Line and ESD- OK. Gas ESD not functional. Gas supply valve frozen- Operations resolving issue. 17:30 - 21 :30 4.00 DRILL P INT2 Continue to single in wi DP (14 jts 4" HWDP and 60 jts 4" DP total). MU XO. 21 :30 - 22:45 1.25 DRILL N SFAL INT2 Lost high line power. Rig electrician troubleshooting. Production was starting LP compessor with 3 turbines on. When it was started they went back to one turbine. The load shed logic had the rig loosing power first. Everything back on line. 22:45 - 00:00 1.25 DRILL P INT2 Strap and TIH wi 5" DP. At midnight, 26 stands in the hole (5021'). 11/19/2001 00:00 - 05:00 5.00 DRILL P INT2 RIH on 5" drillpipe. SLM each stand. RIH to 11,276 ft. Take weight. 05:00 - 06:00 1.00 DRILL P INT2 Wash downl Drill through cement stringers down to 11,408 ft ( Float collar) 06:00 - 07:30 1.50 DRILL P INT2 Drill cement to within 8 ft of shoe to 11,482 ft. Unable to rotate due to high torque in Brine. 07:30 - 10:30 3.00 DRILL P INT2 Displace well to 9.3 ppg Quikdrill system. 10:30 - 13:00 2.50 DRILL N RREP INT2 Low Oil Pressure warning on Top Drive. Change out oil ( Water contaiminated). Build surface volume and build LCM pill @ 60 ppb Baracarb while changing out oil. 13:00 - 14:30 1.50 DRILL P INT2 Drill remainder of shoetrack and 20 ft of new formation to 11,510ft. 14:30 - 15:00 0.50 DRILL P INT2 Circulate until MWin = MW out = 9.3 ppg. 15:00 - 16:00 1.00 DRILL P INT2 Conduct FIT to 11.3 ppg. 1130 psi FIT.4.6 bbls pumpedl returned 16:00 - 00:00 8.00 DRILL P PROD1 PUW 335k, SLW 225k, and ROT 278k. Drill ahead from 11510' to 11761' wi Avg ROP of 35 fph. WOB 20k, Flow 350 gal/min, and RPM 90 rpm. ROP 50-60 fph in the Ivishak. Highest Gas reading 528 units @ 11650 ft. 11/20/2001 00:00 - 11 :30 11.50 DRILL P PROD1 Drlg f/11761' -- 12000' md. Monitored well -- Static. 11 :30 - 13:00 1.50 DRILL P PROD1 Perform Wiper Trip to 7" Shoe @ 11488' md. 13:00 - 14:30 1.50 DRILL P PROD1 CBU -- 6312 stks. 80 units Trip Gas. 14:30 -15:00 0.50 DRILL P PROD1 POOH to 7" casing shoe @ 11488' md. Monitor well -- Static. Drop 2-3/8" rabbit. Pumped Dry Job. 15:00 - 21 :30 6.50 DRILL P PROD1 POOH with 95 stands of 5" dp to xo @ 4" dp. Slowed trip speed to prevent mud from spilling out of drill pipe. Note: RLL -- Should consider running circ sub on future wells to allow allow for more efficient trip speed. 21 :30 - 22:30 1.00 DRILL P PROD1 POOH with 20 stands of 4" dp. Printed: 12/4/2001 9:39:01 AM (' ( BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: 7/9/2001 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 11120/2001 22:30 - 00:00 1.50 DRILL P PROD1 LD 12 joints of 4" HWDP. Note: Operation delayed when a process leak was discovered in PUTZ. See Comments Section. 11/21/2001 00:00 - 01 :00 1.00 DRILL P PROD1 Continue TOH. UD 4" HWDP. Retrieve Drift. 01 :00 - 02:30 1.50 DRILL P PROD1 Change out elevators. LD BHA#7. Remove source and pull probe from MWD. Bit condition- well used. 02:30 - 03:00 0.50 DRILL P PROD1 UD source from floor. Clear and clean floor. Clean suction screens on both pumps. 03:00 - 04:30 1.50 CASE P COMP RIU Tongs and single jt comensator. Prepare to run 4 1/2" Vam-Ace chrome liner. 04:30 - 05:00 0.50 CASE P COMP PJSM. Discuss importance of clean threads, checking seal surface for damage, doping, and stabbing pipe - Crews first experience with Vam-Ace pipe handling. 05:00 - 08:00 3.00 CASE P COMP MU shoe track. Baker locking all threads from top of landing collar to float shoe. Check floats - good. MU and RIH w/16 jts (2 -5 3/4" RH turbolators per jt - Jts 12 and 13 wlo turbolators) wi 4-1/2" chrome Vam-Ace liner. PUW= 80k I SOW= 75k. 08:00 - 09:00 1.00 CASE P COMP Rig down 41/2" chrome liner handling equipment. 09:00 - 1 0:00 1.00 CASE P COMP MU Hanger and ZXP packer. Circulate liner volume. 10:00 - 11 :00 1.00 CASE P COMP TIH wi 4" DP and liner assembly to 2589', fill every 10 stands. 11 :00 - 15:30 4.50 CASE P COMP XO and TIH wi 5" DP and liner assembly to 7205'. 15:30 - 00:00 8.50 CASE N RREP COMP Brushes broke in traction motor "A" on draw works. After further investigation I coupling had slipped causing motor brushes to break. Plan is to isolate "A" traction motor and run draw works on "B" traction motor only. 11/22/2001 00:00 - 02:30 2.50 CASE N RREP COMP Work on Drawworks "A" Traction Motor. Disconnect coupling and isolate to allow operations to continue on "B" Traction Motor. 02:30 - 05:30 3.00 CASE P COMP RiH wiht 4-1/2" liner on 5" dp f/7205' to 7" shoe @ 11440' md. PU = 235K and SO = 215K. 05:30 - 07:30 2.00 CASE P COMP Fill dp and Circ 1.3x BU @ 70 spm -- 625 psi. Gas at BU = 200 units. 07:30 - 08:30 1.00 CASE P COMP RU Baker cementing head on joint of dp and secure in derrick. 08:30 - 09:30 1.00 CASE P COMP Finish RIH with liner to 11970' md -- drift 5 stds of 5" dp out of derrick. 09:30 - 10:00 0.50 CASE P COMP MU Baker Cement Head and RU cement and wash up hoses. 10:00 - 12:00 2.00 CASE P COMP Establish Circ and Slowly increase rate to 72 spm while reciprocating 25' strokes. Notes: Hole started packing off at 50 spm while reciprocating near bottom of stroke at 12000' -- pressure increasing from 500 psi to 1100 psi. Reduce pump rate to 33 spm while pressure reduced only to again start packing off and increasing to 1200 psi. Reduce pump rate to 24 spm and establish reciprocation without incident. Gradually increased rate to 72 spm while reciprocating 20' strokes. Staying 5 feet off bottom due to tendency to pack off in this area. 12:00 - 12:30 0.50 CASE P COMP Finish circulating, pump 5 bbls of sea water and test cement lines to 4000 psi -- ok. Pump 50 bbls of Alpha Spacer @ 10.5 ppg. 12:30 - 13:30 1.00 CASE P COMP Mix and Pump 26.0 bbls of Class G 15.9 ppg production cement blend. Drop wiper dart and wash up Halliburton. Switch to rig and diplace @ 6 bpm for 193 bbls while reciprocating 25 foot strokes -- bumped plug with 3500 psi, Printed: 12/4/2001 9:39:01 AM ( (' BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: 7/9/2001 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 11122/2001 12:30 - 13:30 1.00 CASE P COMP release pressure and check floats - ok. Notes: Positioned liner at bottom while spacer exited the shoe. Reciprocated to top of stroke with cement 200 stks from shoe. Attempted to slack off -- stacked 50K and unable to slack off -- maintained full circulation with no losses. PU and pulled pipe free with 300K (15K overpull) and attempted to return to bottom but stacked up again -- this time stack 1 OOk with no results. Slacked off with 150K with no luck. Cemented liner in place 25' off bottom with full returns throughout job. 13:30 - 14:30 1.00 CASE P COMP Released from liner with 20 turns to the right. Picked up and pumed 20 bbls of mud at 100 spm to clean cement of top of liner. 14:30 - 15:00 0.50 CASE P COMP Stack weight and set packer, PU and rotate 15 rpm and stack weight to set packer. 15:00 - 17:30 2.50 CASE P COMP LD cementing head, stand back one stand and pump dry job. 17:30 - 18:00 0.50 CASE P COMP POOH with 5" dp. 18:00 - 19:00 1.00 CASE N COMP Work on Traction Motor. 19:00 - 23:00 4.00 CASE P COMP Finish POOH with 5" dp. 23:00 - 00:00 1.00 CASE P COMP Change over to 4" handling equipment to include heads in iron rough neck. 11/23/2001 00:00 - 01 :30 1.50 CASE P COMP POOH wi 4" dp -- LD 9 jts and Baker Running Tool. 01 :30 - 02:30 1.00 CASE P COMP Pressure Test Liner Lap to 3400 pis fo 30 min with 9.3 ppg. Blow Down choke and kill lines. 02:30 - 08:00 5.50 CLEAN P COMP RU 2-3/8" handling equip; RIH with motor wi circ sub and mill on 20 joints of 2-3/8" dp; RD 2-3/8" handling equip and RU 4" handling equip while MU crossovers, 7" 26" casing scraper and 4" PBL sub; RIH with 44 joints of 4" dp -- lay down 4 jts of4" dp. MU 9-5/8" casing scraper and crossover. 08:00 - 09:30 1.50 CLEAN P COMP RIH with 5" dp f/2057' to 4913' md. 09:30 - 10:00 0.50 CLEAN P COMP Fill dp and circ to check motor -- 20 spm @ 350 psi. 10:00 - 12:00 2.00 CLEAN P COMP RiH fl 4913' - 8713' md. 12:00 - 18:00 6.00 CLEAN P COMP RiH f/8713' - 11969'. 18:00 - 00:00 6.00 CLEAN N DPRB COMP Mill on plug and cement. FS - 22 spm/560 psig. Tag down at 11868'. Very slow milling. 11/24/2001 00:00 - 15:00 15.00 CLEAN N DPRB COMP Milling on plug. No sign of rubber over shakers. Milling very slow. Making progress for short periods and then no progress--suspect rubber preventing a good penetration rate. Mix high visc pill and stage 5 bbls sweeps every 30 mins. Rotate on plug wi top-drive. Finally, mill through landing collar and continue wi good penetration rate down to 11910'. 15:00 - 15:30 0.50 CLEAN P COMP Circulate and work pipe through liner. 15:30 - 16:00 0.50 CLEAN P COMP Test 4 1/2" liner and casing to 3400 psig- good. 16:00 - 21:00 5.00 CLEAN P COMP Break connection. Drop 3/4" ball and open circ-sub. Circulate in SW and out 9.3 mud. Able to achieve rate of 11-12 bpm and GI to keep up with. Pump a total of 10601 strokes I and have clean SW back. Unable to reciprocate and pump at same time with drawworks traction motor "A" still locked out. Will reciprocatel rotatate on next circulation. 21 :00 - 00:00 3.00 CLEAN P COMP Pull one stand and install SV. Monitor well for underbalance test-good. G & I injecting mud - making room for next circulation. Out of the critical path, the rig mechanic and crew installing traction motor "A" and Baroid getting ready to mix caustic wash, BARAKLEAN wash, and high visc sweep for final Printed: 12/4/2001 9:39:01 AM (" ( BP EXPLORATION Page 12 of 14 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: 7/9/2001 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 11124/2001 21 :00 - 00:00 3.00 CLEAN P COMP cleanup. 11/25/2001 00:00 - 02:00 2.00 CLEAN P COMP G & I continue to inject mud and SW returns from mud displacement to SW. Making room for next casing wash circulation. Rig crew still working on 'A' traction motor installation. Finding more troubles than anticipated. 02:00 - 09:00 7.00 CLEAN N RREP COMP Working on traction motor- in critical path. 09:00 - 09:30 0.50 CLEAN P COMP PJSM wi Baroid on pumping caustic and Baraklean sweeps. 09:30 - 12:30 3.00 CLEAN N FLUD COMP Thaw out frozen mudline and standpipe elbow. 12:30 - 16:00 3.50 CLEAN P COMP Pump caustic, baraklean, and high vis sweeps. Chase wi filtered SW until @ 13 bpm and 4100 psig through 2 3/8" (10 holes) circ sub. At 900 bbls have 60 NTU's. After 1000 bbls SW quality 45 NTU's. 16:00 - 00:00 8.00 CLEAN P COMP TOH wi tapered cleanout string. 11/26/2001 00:00 - 02:00 2.00 CLEAN P COMP Continue TOH. Lay down 2 3/8" DP. 02:00 - 03:00 1.00 CLEAN P COMP Lay down BHA #8. Clear and clean floor. 03:00 - 07:30 4.50 RUNCor fP COMP RU to run completion. Pull wear ring. Change Bails and Elevators. Hang Sheaves and Cidra cable and 41/2" handling equipment. 07:30 - 08:00 0.50 RUNCO~ Ip COMP Make up tail pipe assembly and BOT S-3 packer. 08:00 - 10:30 2.50 RUNCO~ t.J SFAL COMP MU x nipple -- overtorqued x nipple assy due to broken connection on cable to torque turn machine -- replaced cable. Back out x nipple and change cplg. MU second x nipple assy and overtorque due to faulty dump valve on tubing tongs -- replaced dump valve. Sucessfully made up the x nipple assy. 10:30 - 11 :00 0.50 RUNCO~ Ip COMP MU Cidra mandrel assy and tubing joint #1. Install the press and temp transducer. 11 :00 - 12:00 1.00 RUNCO~ Ip COMP Test Cidra Mandrell to 7500 psi. Good Test. 12:00 - 13:00 1.00 RUNCO~ Ip COMP Crew Change. Review Cidra fiber optic cable running procedures with the crews (Nabors, Cidra, Weatherford and Nabors casing). 13:00 - 00:00 11.00 RUNCO~ Ip COMP Rih wi completion. Crews are running 4.5" 13-CR Vam-Ace tubing at a rate of 10-11 jtsl hr. At midnight -125 jts RIH. 11/27/2001 00:00 - 10:00 10.00 RUNCor Ip COMP RIH with 4-1/2" chrome tubing to SVLN @ joint 214. 10:00'- 10:30 0.50 RUNCor Ip COMP MU SVLN, 2 control lines and pressure test -- ok. 10:30 - 16:00 5.50 RUNCor /P COMP Continue RIH with remaining 4-1/2" chrome tubing (264 total joints). 16:00 - 17:00 1.00 RUNCO~ Ip COMP Tag top of 4-1/2" tie back receptacle. PU and repeat tag for depth confirmation. Perform Space out to position WLEG 3' into the top of the 4-1/2" liner tie back receptacle). 17:00 - 18:30 1.50 RUNCO~ Ip COMP MU Tubing Hanger and rotate tubing string 45 degrees to align control port in hanger with the test port in the tubing spool -- this is necessary to ensure that no control ports in the tubing hanger (3 ea @ 120 deg orientation) are aligned with an exit port in the tubing spool flange (4 ea @ 90 degree orientation). Alignment of the exit ports blocks the access for the control lines to exit the ports in the tubing spool. 18:30 - 20:30 2.00 RUNCor Ip COMP Route the SSSV control lines and the fiber optics cable through the exit ports in the tubing hanger. Peel the insulation from the fiber optic cable and make a splice to allow continuous monitoring while landing hanger. Test the cidra cable splice -- good test. 20:30 - 21 :30 1.00 RUNCor Ip COMP Land tubing hanger, run in lock down screws and test to 5000 psi. Test fiber optic cable -- good test. Read BHT at 221 deg Printed: 12/4/2001 9:39:01 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date (' ( BP EXPLORATION Operations Summary Report NS13 NS13 DRILL +COMPLETE NABORS NABORS 33E Page 13 of 14 Start: 6/14/2001 Rig Release: 7/9/2001 Rig Number: 33E Spud Date: 6/16/2001 End: From - To Hours Activity Code NPT Phase Description of Operations 11/27/2001 20:30 - 21 :30 21 :30 - 00:00 11/28/2001 00:00 - 05:00 COMP COMP COMP 05:00 - 09:30 COMP 09:30 - 12:00 COMP 12:00 - 15:00 COMP 15:00 - 15:30 COMP 15:30 - 17:30 COMP 17:30 - 18:00 COMP 18:00 - 00:00 COMP 11/29/2001 00:00 - 03:00 COMP 03:00 - 04:30 04:30 - 05:00 COMP COMP 05:00 - 06:30 COMP 06:30 - 07:00 COMP 07:00 - 00:00 COMP 11/30/2001 00:00 - 00:30 COMP 00:30 - 04:30 COMP 04:30 - 08:30 COMP 08:30 - 13:00 COMP 13:00 - 13:30 COMP 13:30 - 15:30 COMP 15:30 - 18:00 COMP F and pressure. NO the riser and begin nippling down the BOPE -- break flange between double gate and mud cross. BO landing joint, RD spooling units and sheaves and clear the rig floor out of critical path. Split stack betweent the double gate and the mud cross. Rack back in BOPE Rack -- tight fit -- LL found it necessary to rotate stack on swivel and orient hydraulic fitting to the west in order to set stack in rack. Wrap and terminate control lines and exit through the tubing spool flange. NU Tree -- test tubing bonnet to 5000 psi 115 minutes. Fill tree with diesel and test to 5000 psi for 15 minutes. RU circulating manifold. Finish RU manifold and line up for circulating down annulus taking returns up tubing. Hold pre-job meeting for freeze protecting the well. Test manifold -- repair leaks in hammer unions in circulating maniflod. Finish pressure test. Pump 180 bbls corexit treated heated sea water, 5 bbls of heated mineral oil, 275 bbls of diesel and 5 bbls of heated mineral oil. Pumping diesel at midnite at 1 bpm. Finish pumping diesel down annulus through circulating manifold and lined up manifold valving to U-tube. Total diesel pumped was 275 bbls. followed by 5 bbls of mineral oil. Drop 1 7/8" ball and rod for setting packer. Pressure up on tubing to 4200 psi, set packer, and held for 30 minutes. (see chart) Bleed pressure off of tubing down to 3000 psi and pressure test annulus to 4200 psi. Held for 30 minutes, good test. (see chart) Bled pressure off of annulus to 3500 psi and held while bleeding pressure off of tubing to shear RP valve. Bleed off pressure to 0 psi. Blow down all lines, break down circulating manifold and lines, & clear cellar. PJSM on rigging up Schlumberger and rig up. Slickline operations. Complete runs # 1 through # 7 out of a total of 8. POH with slickline run # 8. (Drift tubing & liner with gauge ring) RD slickline & RU E-line. Make-up USIT tools. Run USIT log. RU Schlumberger for perforating ops. RU perf guns, smallline, & lubricator. PJSM with rig crew & Schlumberger. Arm perforating gun & test lubricator to 3000 psi. RIH with perf. gun run # 1. Interval perforated - 11,844 to 11,864. Good indication at surface. Wellhead pressure went from 50 psi to 550 psi. Bottom hole pressure from fibreoptics showed BHP from 4290 Printed: 12/4/2001 9:39:01 AM ( (' BP EXPLORATION Page 14 of 14 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: 7/9/2001 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 11130/2001 15:30 - 18:00 2.50 RUNCO~ Ip COMP psi to 4900 psi. 18:00 - 18:30 0.50 RUNCO~1p COMP PJSM with new crew. 18:30 - 00:00 5.50 RUNCO~ Ip COMP RIH with perf gun run # 2. Interval perforated - 11814' to 11844' 12/1/2001 00:00 - 05:30 5.50 RUNCO~ Ip COMP RIH with perf. gun run # 3. POH & laydown perf gun. Change 0 ring on lubricator & test to 3000 psi. Change firing head. Perforation interval - 11784' to 11814'. 05:30 - 09:00 3.50 RUNCO~ Ip COMP RIH with perf. gun run # 4. Gun didn't fire. POH & change firing head. MU perf gun 4A. 09:00 - 14:30 5.50 RUNCO~ Ip COMP RIH with perf gun run # 4A. Gun didn't fire. POH & LD gun. Change out rope socket. 14:30 - 16:30 2.00 RUNCO~ Ip COMP RIH with perf gun run # 4B. Succesful. Perforation interval - 11754' to 11784' 16:30 - 19:00 2.50 RUNCO~ /P COMP RIH with perf gun run # 5. Perforation interval - 11724' to 11754' 19:00 - 19:30 0.50 RUNCO~ /P COMP PJSM on LD lubricator & E-line 19:30 - 20:30 1.00 RUNCor Ip COMP LD lubricator & E-line. 20:30 - 21 :00 0.50 RUNCO~ Ip COMP PJSM on slickline RU. 21 :00 - 00:00 3.00 RUNCO~ Ip COMP RU slickline, BOP's, slip line & retie rope socket, pressure test lubricator. 12/2/2001 00:00 - 08:00 8.00 RUNCO~ Ip COMP RIH with slickline & attemp to set SSSV. Set on 3rd attempt. POH and LD tools in cellar & pipeshed. 08:00 - 12:00 4.00 RUNCO~ Ip COMP RU Vetco Gray to set BPV. Lubricator wouldn't fit through drip pan. LD & bring through cellar. Install BPV, shut in well, LD lubricator & clean up cellar. 12:00 - 14:00 2.00 RUNCO~ Ip COMP Clear tools from rig floor. Release rig from NS-13 @ 1400 hours Printed: 12/4/2001 9:39:01 AM ANADRILL SCHLUMBERGER Survey report Client.. .... .............: BP Exploration (Alaska) Inc. Field............... .....: Northstar Well. . . . . . . . . . . . . . . . . . . . .: NS13 API number........ .......: 50-029-20317-00 Engineer...... ...........: Rathert Rig:.....................: Nabors 33E State:...................: Alaska ----- Survey calculation methods------------- Method for positions.. ...: Minimum curvature Method for DLS...... .., ..: Mason & Taylor ----- Depth reference Permanent datum.. ........: Depth reference....... ...: GL above permanent..... ..: KB above permanent.......: DF above permanent.... ...: ------ Mean Sea Level Drill Floor 15.67 ft NA 56.19 ft ----- Vertical section origin-------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)..... ...: 0.00 ft ----- Platform reference point- Latitude (+N/S-).. .......: -999.25 ft Departure (+E/W-)...... ..: -999.25 ft Azimuth from rotary table to target: 283.23 degrees [(c)2001 Anadrill IDEAL ID6_1C_l0J 20-Nov-2001 20:26:27 Spud da t e. . . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 6 16-June-Ol 20-Nov-Ol 134 0.00 ft 12000.00 ft ~- ----- Geomagnetic data ---------------------- Magnetic model. ..........: BGGM version 2000 Magnetic date.. ....,.. ...: 16-Nov-2001 Magnetic field strength..: 1149.88 HCNT Magnetic dec (+E/W-).....: 26.61 degrees Magnetic dip... ....... ...: 80.92 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G. . . . . . . . . . . . . . : H..............: Dip. . . . . . . . . . . . : of G...........: of H...........: of Dip.........: Criteria --------- 1002.69 mGal 1150.18 HCNT 80.93 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees -- ----- Corrections Magnetic dec (+E/W-)... ..: Grid convergence (+E/W-).: Total az corr (+E/W-)....: (Total az corr = magnetic dec Sag applied (Y/N) ...... ..: No ---------- 26.61 degrees 0.00 degrees 26.61 degrees - grid conv) degree: 0.00 ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 21 22 23 24 25 26 27 28 29 30 -------- -------- 1 2 3 4 5 0.00 50.00 100.00 150.00 180.00 ------ ------ Incl angle (deg) ------ ------ 0.00 0.40 0.70 1.20 1.30 0.40 0.17 0.19 0.06 0.05 0.02 0.05 0.07 0.08 0.28 0.46 0.52 0.37 0.49 0.32 0.32 0.46 0.57 0.49 0.42 0.53 0.29 0.29 1.60 3.21 ------- ------- ------ ------ Azimuth Course angle length (deg) ( f t) ------- ------- 0.00 125.40 143.40 145.60 144.10 145.80 79.49 54.83 351.08 43.86 11.16 340.04 307.20 289.63 320.95 351.51 10.27 12.01 23.36 7.92 346.05 4.18 344.88 352.48 348.78 19.97 43.28 27.52 281.69 282.08 ------ ------ 0.00 50.00 50.00 50.00 30.00 90.00 94.90 91.10 91.00 91.00 91.00 91.10 91.00 95.20 21.22 97.23 93.71 97.56 95.08 95.46 95.29 94.58 95.07 94.28 96.27 93.86 96.05 95.84 95.10 95.19 [(c)2001 Anadrill IDEAL ID6_1C_10] 6 7 8 9 10 270.00 364.90 456.00 547.00 638.00 11 12 13 14 15 729.00 820.10 911.10 1006.30 1027.52 16 17 18 19 20 1124.75 1218.46 1316.02 1411.10 1506.56 1601.85 1696.43 1791.50 1885.78 1982.05 2075.91 2171.96 2267.80 2362.90 2458.09 -------- -------- TVD depth (ft) -------- -------- 0.00 50.00 100.00 149.99 179.98 269.97 364.87 455.97 546.97 637.97 728.97 820.07 911.07 1006.27 1027.49 1124.72 1218.42 1315.98 1411.06 1506.52 1601.81 1696.38 1791.45 1885.72 1981.99 2075.85 2171.90 2267.74 2362.82 2457.93 20-Nov-2001 20:26:27 -------- -------- Vertical section (ft) -------- -------- 0.00 -0.16 -0.56 -1.18 -1.67 -2.67 -3.04 -3.27 -3.35 -3.35 -3.37 -3.35 -3.28 -3.16 -3.10 -2.77 -2.61 -2.58 -2.64 -2.69 -2.54 -2.36 -2.08 -1.71 -1.42 -1.33 -1.50 -1.69 -0.42 3.58 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 0.00 -0.10 -0.45 -1.12 -1.66 -2.75 -2.99 -2.88 -2.75 -2.67 -2.63 -2.58 -2.51 -2.45 -2.40 -1.83 -1.04 -0.30 0.38 1.01 1.54 2.17 3.01 3.86 4.62 5.36 5.96 6.35 6.83 7.66 0.00 0.14 0.47 0.94 1.32 2.10 2.42 2.68 2.79 2.81 2.84 2.83 2.78 2.67 2.62 2.41 2.43 2.58 2.80 3.00 2.97 2.94 2.84 2.67 2.55 2.63 2.94 3.22 2.03 -1.87 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 0.00 0.17 0.65 1.47 2.12 3.46 3.85 3.93 3.92 3.88 3.87 3.83 3.74 3.62 3.56 3.03 2.65 2.60 2.83 3.17 3.35 3.65 4.14 4.69 5.27 5.97 6.64 7.12 7.13 7.88 0.00 125.40 133.79 139.97 141.47 142.64 141.04 137.11 134.54 133.53 132.75 132.27 132.06 132.54 132.51 127.20 113.17 96.59 82.36 71.33 62.68 53.54 43.38 34.64 28.88 26.10 26.31 26.92 16.59 346.25 2 of 6 DLS (degl 100f) 0.00 0.80 0.69 1.00 0.35 1.00 0.39 0.09 0.19 0.05 0.04 0.04 0.04 0.03 1.02 0.27 0.18 0.15 0.15 0.21 0.13 0.20 0.21 0.11 0.08 0.29 0.30 0.08 1.79 1.69 TIP GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ------ ------ Srvy tool type 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 ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 51 52 53 54 55 56 57 58 59 60 -------- -------- 31 32 33 34 35 2553.84 2649.80 2744.21 2838.85 2933.95 ------ ------ Incl angle (deg) ------ ------ 5.54 7.94 10.46 13.10 15.23 17.36 19.10 19.36 19.87 21.15 22.22 24.14 27.51 28.26 28.71 30.08 30.27 29.87 29.37 29.07 28.90 29.65 29.32 28.81 28.98 29.14 28.52 28.95 29.40 30.15 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 287.53 285.48 281.76 282.17 282.16 283.50 280.65 281.54 281.59 281.64 279.60 279.40 280.23 280.94 283.41 283.03 284.00 283.31 281.33 280.42 281.55 280.14 283.15 282.71 284.20 286.39 285.77 287.44 286.67 287.04 ------ ------ 95.75 95.96 94.41 94.64 95.10 95.67 95.32 16.79 76.43 94.88 95.37 95.09 95.21 95.12 95.91 93.84 95.82 95.95 94.33 95.08 95.45 94.78 95.18 94.85 95.10 96.54 95.00 94.80 95.33 94.27 [(c)2001 Anadrill IDEAL ID6_1C_10] 36 37 38 39 40 3029.62 3124.94 3141.73 3218.16 3313.04 41 42 43 44 45 3408.41 3503.50 3598.71 3693.83 3789.74 46 47 48 49 50 3883.58 3979.40 4075.35 4169.68 4264.76 4360.21 4454.99 4550.17 4645.02 4740.12 4836.66 4931.66 5026.46 5121.79 5216.06 -------- -------- TVD depth (ft) -------- -------- 2553.39 2648.68 2741.87 2834.51 2926.71 3018.53 3109.07 3124.92 3196.92 3285.78 3374.40 3461.81 3547.50 3631.57 3715.88 3797.63 3880.47 3963.51 4045.51 4128.49 4211.99 4294.66 4377.52 4460.42 4543.69 4628.08 4711.30 4794.43 4877.66 4959.49 20-Nov-2001 20:26:27 -------- -------- Vertical section (ft) -------- -------- 10.87 22.11 37.20 56.51 79.78 106.62 136.42 141.95 167.59 200.82 236.02 273.37 314.76 359.20 404.93 450.98 499.15 547.22 593.83 640.20 686.42 732.72 779.54 825.62 871.57 918.42 964.17 1009.67 1056.03 1102.75 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 9.61 12.77 16.26 20.27 25.18 31.16 37.36 38.42 43.57 50.26 56.74 62.92 70.00 78.18 87.83 98.36 109.62 120.97 130.92 139.68 148.49 157.20 166.65 176.96 187.66 200.03 212.72 225.74 239.37 252.95 -8.90 -19.71 -34.39 -53.28 -76.03 -102.20 -131.36 -136.78 -161.92 -194.48 -229.11 -266.03 -306.89 -350.62 -395.32 -440.16 -486.98 -533.70 -579.24 -624.82 -670.23 -715.74 -761.61 -806.52 -851.21 -896.43 -940.45 -984.12 -1028.55 -1073.35 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 13.10 23.49 38.04 57.01 80.09 106.84 136.56 142.08 167.68 200.87 236.03 273.37 314.77 359.23 404.96 451.01 499.17 547.24 593.85 640.24 686.48 732.80 779.63 825.71 871.65 918.48 964.21 1009.68 1056.04 1102.75 317.19 302.95 295.31 290.83 288.32 286.96 285.88 285.69 285.06 284.49 283.91 283.31 282.85 282.57 282.53 282.60 282.69 282.77 282.74 282.60 282.49 282.39 282.34 282.38 282.43 282.58 282.75 282.92 283.10 283.26 3 of 6 DLS (deg/ 100f) 2.47 2.51 2.74 2.79 2.24 2.26 2.05 2.33 0.67 1.35 1.37 2.02 3.56 0.86 1.31 1.47 0.55 0.55 1.16 0.56 0.60 1.07 1.59 0.58 0.78 1.11 0.72 0.96 0.61 0.82 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ------ ------ Srvy tool type 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 ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 81 82 83 84 85 86 87 88 89 90 -------- -------- 61 62 63 64 65 5311.34 5406.83 5501.26 5597.29 5692.77 ------ ------ Incl angle (deg) ------ ------ 30.47 29.94 29.55 29.04 28.58 29.37 29.57 28.91 29.71 29.83 30.39 30.56 30.44 29.91 29.50 28.99 29.35 29.50 29.66 29.47 29.16 28.65 28.75 28.65 28.83 28.71 28.21 28.04 27.99 27.34 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 287.44 286.78 285.14 286.02 285.56 287.32 289.30 287.66 286.78 287.09 285.56 284.36 284.54 284.37 284.39 284.63 283.74 283.37 283.55 282.13 281.73 282.09 281.33 281.22 281.68 281.59 281.00 281.35 281.61 281.83 ------ ------ 95.28 95.49 94.43 96.03 95.48 95.45 94.42 95.55 95.59 93.93 94.96 91.56 28.63 96.18 93.68 93.28 95.07 97.48 93.94 96.02 94.05 96.06 94.91 95.40 93.90 94.62 95.42 96.03 95.70 95.71 [(c)2001 Anadrill IDEAL ID6_1C_10] 66 67 68 69 70 5788.22 5882.64 5978.19 6073.78 6167.71 71 72 73 74 75 6262.67 6354.23 6382.86 6479.04 6572.72 76 77 78 79 80 6666.00 6761.07 6858.55 6952.49 7048.51 7142.56 7238.62 7333.53 7428.93 7522.83 7617.45 7712.87 7808.90 7904.60 8000.31 -------- -------- TVD depth (ft) -------- -------- 5041.74 5124.27 5206.26 5290.01 5373.67 5457.17 5539.38 5622.75 5706.11 5787.64 5869.79 5948.70 5973.37 6056.51 6137.88 6219.27 6302.29 6387.19 6468.89 6552.41 6634.41 6718.51 6801.76 6885.44 6967.77 7050.71 7134.60 7219.29 7303.77 7388.54 20-Nov-2001 20:26:27 -------- -------- Vertical section (ft) -------- -------- 1150.72 1198.65 1245.44 1292.39 1338.36 1384.52 1430.78 1477.25 1523.93 1570.47 1618.04 1664.45 1678.98 1727.31 1773.72 1819.28 1865.61 1913.50 1959.87 2007.25 2053.28 2099.70 2145.26 2191.05 2236.18 2281:70 2327.14 2372.38 2417.31 2461.74 Page ---------------- --------------- --------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) ---------------- --------------- ---------------- 267.20 281.33 294.22 306.84 319.36 332.45 347.04 361.84 375.69 389.28 402.66 414.65 418.27 430.34 441.87 453.29 464.64 475.86 486.66 497.19 506.71 516.29 525.54 534.50 543.46 552.64 561.55 570.32 579.27 588.30 -1119.28 -1165.19 -1210.23 -1255.49 -1299.76 -1344.11 -1388.20 -1432.46 -1477.16 -1521.77 -1567.49 -1612.35 -1626.42 -1673.23 -1718.20 -1762.32 -1807.24 -1853.80 -1898.89 -1945.08 -1990.14 -2035.57 -2080.20 -2125.13 -2169.38 -2213.98 -2258.57 -2302.98 -2347.03 -2390.54 --------------- 1150.73 1198.67 1245.48 1292.44 1338.42 1384.61 1430.92 1477.45 1524.18 1570.77 1618.38 1664.81 1679.34 1727.69 1774.11 1819.68 1866.01 1913.90 1960.26 2007.62 2053.63 2100.02 2145.56 2191.31 2236.41 2281.91 2327.33 2372.55 2417.46 2461.87 283.43 283.57 283.66 283.73 283.80 283.89 284.04 284.18 284.27 284.35 284.41 284.42 284.42 284.42 284.42 284.42 284.42 284.40 284.37 284.34 284.28 284.23 284.18 284.12 284.06 284.02 283.96 283.91 283.86 283.83 4 of 6 DLS (deg/ 100f) 0.40 0.65 0.96 0.70 0.53 1.22 1.05 1.09 0.95 0.21 1.00 0.69 0.53 0.56 0.44 0.56 0.59 0.24 0.19 0.76 0.39 0.56 0.40 0.12 0.30 0.13 0.60 0.25 0.14 0.69 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ------ ------ Srvy tool type 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 ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 -------- -------- 91 92 93 94 95 8095.56 8190.72 8285.60 8381.32 8476.90 ------ ------ Incl angle (deg) ------ ------ 26.70 25.99 25.17 24.39 23.43 22.58 22.26 21.78 20.90 20.30 20.07 19.69 19.39 18.24 16.02 14.56 13.10 11.79 10.57 9.57 7.79 7.72 7.32 6.52 5.94 5.74 5.46 5.27 4.93 4.77 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 281.50 282.01 282.00 282.55 282.27 282.84 283.08 282.86 283.63 284.13 283.85 285.58 285.55 284.15 283.04 282.82 281.02 281.84 281.50 282.33 283.42 284.06 286.37 285.12 280.87 287.32 287.41 288.02 285.19 290.86 ------ ------ 95.25 95.16 94.88 95.72 95.58 96.55 95.23 94.59 95.10 95.57 95.10 95.65 94.68 95.64 95.25 95.18 95.14 94.52 95.87 94.27 94.66 16.87 133.71 94.45 94.83 94.79 95.65 94.73 95.00 94.44 [(c)2001 Anadrill IDEAL ID6_1C_10J 8573.45 8668.68 8763.27 8858.37 8953.94 9049.04 9144.69 9239.37 9335.01 9430.26 9525.44 9620.58 9715.10 9810.97 9905.24 9999.90 10016.77 10150.48 10244.93 10339.76 10434.55 10530.20 10624.93 10719.93 10814.37 -------- -------- TVD depth (ft) -------- -------- 7473.39 7558.67 7644.25 7731.16 7818.53 7907.40 7995.44 8083.13 8171.70 8261.16 8350.42 8440.37 8529.60 8620.13 8711.15 8802.96 8895.34 8987.63 9081.68 9174.50 9268.07 9284.79 9417.35 9511.11 9605.38 9699.68 9794.87 9889.19 9983.81 10077.91 20-Nov-2001 20:26:27 -------- -------- Vertical section (ft) -------- -------- 2504.99 2547.21 2588.16 2628.28 2667.01 2704.74 2741.06 2776.52 2811.13 2844.75 2877.56 2910.08 2941.72 2972.55 3000.60 3025.70 3048.43 3068.79 3087.37 3103.85 3118.13 3120.41 3137.89 3149.26 3159.54 3169.17 3178.48 3187.31 3195.74 3203.69 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 597.05 605.65 614.17 622.70 631.02 639.22 647.37 655.33 663.25 671.31 679.25 687.50 696.00 703.92 710.53 716.15 720.86 724.89 728.65 732.05 735.22 735.76 740.34 743.44 745.77 748.10 750.89 753.58 756.00 758.46 -2432.92 -2474.27 -2514.34 -2553.54 -2591.37 -2628.20 -2663.60 -2698.16 -2731.84 -2764.49 -2796.33 -2827.79 -2858.29 -2888.10 -2915.36 -2939.82 -2962.07 -2982.03 -3000.24 -3016.37 -3030.29 -3032.51 -3049.39 -3060.34 -3070.36 -3079.70 -3088.61 -3097.05 -3105.13 -3112.72 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 2505.11 2547.31 2588.26 2628.37 2667.10 2704.82 2741.14 2776.60 2811.20 2844.83 2877.64 2910.16 2941.81 2972.65 3000.70 3025.79 3048.52 3068.88 3087.45 3103.93 3118.21 3120.49 3137.98 3149.35 3159.63 3169.26 3178.57 3187.41 3195.84 3203.79 283.79 283.75 283.73 283.70 283.69 283.67 283.66 283.65 283.65 283.65 283.65 283.66 283.69 283.70 283.70 283.69 283.68 283.66 283.65 283.64 283.64 283.64 283.65 283.65 283.65 283.65 283.66 283.68 283.68 283.69 5 of 6 DLS (deg/ 100f) 0.69 0.78 0.86 0.85 1.01 0.91 0.35 0.51 0.97 0.65 0.26 0.73 0.32 1.29 2.36 1.54 1.60 1.40 1.27 1.07 1.89 0.66 0.37 0.86 0.78 0.72 0.29 0.21 0.45 0.53 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ------ ------ Srvy tool type 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 ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 121 122 123 124 125 126 127 128 129 130 -------- -------- 10909.06 11005.44 11101.13 11195.17 11289.54 11385.30 11420.14 11515.93 11603.90 11708.34 131 11802.31 132 11897.37 133 11920.78 ------ ------ Incl angle (deg) ------ ------ 4.35 4.24 4.28 4.08 3.87 3.76 3.59 3.48 3.23 3.43 ------- ------- ------ ------ Azimuth Course angle length (deg) (ft) ------- ------- 293.37 301.83 312.13 316.72 320.39 326.12 324.63 326.59 328.90 335.10 3.61 335.32 3.64 336.06 3.59 325.21 ------ ------ 94.69 96.38 95.69 94.04 94.37 95.76 34.84 95.79 87.97 104.44 -------- -------- TVD depth (ft) -------- -------- 10172.30 10268.41 10363.84 10457.63 10551.77 10647.32 10682.09 10777.70 10865.52 10969.78 93.97 11063.57 95.06 11158.44 23.41 11181.81 Survey projected to total depth: 134 12000.00 3.59 325.21 79.22 11260.87 [(c)2001 Anadrill IDEAL ID6_1C_10] 20-Nov-2001 20:26:27 -------- -------- Vertical section (ft) -------- -------- 3211.12 3218.10 3224.58 3230.44 3235.78 3240.65 3242.31 3246.67 3250.35 3254.33 3257.88 3261.55 3262.54 3266.23 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 761.29 764.62 768.88 773.67 778.57 783.66 785.50 790.37 794.72 800.08 -3119.69 -3126.08 -3131.73 -3136.63 -3140.96 -3144.77 -3146.04 -3149.37 -3152.12 -3154.96 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 3211.24 3218.23 3224.73 3230.63 3236.01 3240.94 3242.62 3247.04 3250.77 3254.83 283.71 283.74 283.79 283.86 283.92 283.99 284.02 284.09 284.15 284.23 805.32 -3157.38 3258.46 284.31 810.79 -3159.85 3262.22 284.39 812.07 -3160.57 3263.23 284.41 816.15 -3163.40 3266.99 284.47 6 of 6 DLS (deg/ 100f) 0.49 0.67 0.80 0.41 0.35 0.41 0.56 0.17 0.32 0.39 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 0.19 MWD 0.06 MWD 2.93 MWD 0.00 ------ ------ Srvy tool type Tool qual type ------ ------ 6-AXIS 6-AXIS 6-AXIS 6-AXIS 6-AXIS 6-AXIS 6-AXIS 6-AXIS 6-AXIS 6-AXIS .-ò. 6-AXIS 6-AXIS 6-AXIS Proj ~ I I I I I I I I I I [ [ I I I [ I [ [ 2ol-0B~ spe""'I'\f-sun C A I L.L.I N Ci 5 E A V I c: E 5 BP EXPLORATION ALASKA END OF WELL REPORT NORTHSTAR NS-13 I I I TABLE OF CONTENTS I I 1. General Information I 2. Daily Summary 3. Daily O.perations I 4. Show Reports I 5. Morninp Reports 6. BHA's I 7. Bit Record I 8. Mud Reports 9. Surv~y Record I 10. Formation Tops I 11. Formation Evaluation Lo~s I I I apar'I""V-5un I C pi{ .1..1... N Iii .E A\I. c; &:. I I 'I I I [ I I I I I I I I I I I I I I GENERAL WELL INFORMATION Company: Rig: Well : Field: Borough: State: Country: API 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-13 Northstar North Slope Alaska United States 50-029-23017-00 AKAM11103 June 16, 2001 July 03, 2001 True 26.76 deg 80.91 deg 1149.81 HCNT June 14, 2001 North 70 deg 29 min 27.88 sec East 148 deg 41 min 35.85 sec 283.23 deg Doug Wilson Mark Lindloff Wayne Hermanson Paul Lockwood Steve Christian Joe Polya Mike Dinger Ken Lemley Northstar 40087 Alaska North Slope spar'I-.y-sun CRILLI N II BEPI\lIC.. I I I I I I BP Exploration - Northstar NS13 Daily Summary 06-14-2001 - Released rig trom NS-27 at 21 :00 hrs. Moved rig to NS-13. 06-15-2001 - Finish moving rig to NS-13. Rig up supply lines between pipe rack and rig. General rig up of mats, berms, forklift ramp, etc. Hold pre-spud meetings with night and day crews. Complete rigging up riser. Place miscellaneous BRA tools on rig floor. 06-16-2001 - Make up BRA #1. Install derrick safety bar. Hang wireline sheaves for Gyro. Run in and tag ice plug at 55'. Drilled ice plug and picked up HWDP. Tagged gravel at 156' and washed to 229'. POOH and make up BRA #2. Directional drilled 16" hole trom 229' to 1105'. 06-17-2001 - Drilled 16" hole from 1105' to 3175'. 06-18-2001-Drilled 16" hole trom 3175' to 3215'. Pumped Hi-Vis sweep and circulated it out. Wiper tripped to HWDP, with one tight spot at 3108' (30k Ibs overpull). No problems and no fill on the trip in. Bottoms up was circulated twice. The bit was pulled with no problems. Ran 13 3/8' casing to 3195'. Floorhand was injured while screwing a lifting eye into the top of the fill- up tool. Drilling activities were suspended for further evaluation. 06-19-2001 - Accident review was completed and the casing fill-up tool rigged down. Cementing equipment was rigged up and 13 3/8" casing was cemented in two stages. A planning meeting was held to let all personnel know about Government approval for drilling ahead on NS-13. Laid down landing joint. Washed out BOP's. Oriented new rig crew and laid down 16" BRA. 06-20-2001 - Oriented new rig personnel. Nippled down riser and diverter. Set riser on NS-14 well. Nippled up BOP's and related equipment. Urinalysis of crew. Tested BOP's - had to tighten down bolts, etc. before successfully testing BOP's. Installed wear ring and serviced top drive. 06-21-2001 - Made up BHA #3 and directional equipment. Ran in to top ofES cementer and tested casing to 1000 psi for 5 minutes. Drilled out ES cementer and tested casing to 1000 psi for 5 minutes. Ran in hole to landing collar and washed down to top of cement at 3166'. Conditioned mud to 9.2 ppg all around. Tested casing to 2500 psi for 30 minutes. Reviewed Dl, D2 and D5 drills with rig crews and perfonned a D5 drill. Drilled cement, float collar, float shoe and new hole to 3245'. Mud was badly clobbered from cement contamination. Circulated and conditioned mud to 8.7 ppg around and performed a formation leak- off test to 12.5 ppg MWE. The hole was displaced to new mud and directional drilling proceeded from 3215' to 3593', building angle £fom 21° to 30°. 06-22-2001 - Drilled 12 1,4" hole from 3593' to 4256'. Circulated a Hi-Vis sweep and wiper tripped to shoe. Note: 30 k overpull on stand 5 & 6 and swabbed on stand 7. Stand 7 OK after wiping through. Ran back to bottom and drilled 12 Y4" hole trom 4256' to 5116'. 06-23-2001 - Dilled 12 ~" hole from 5116' to 5209'. Finished circulating Hi-Vis sweep. Wiper tripped to 4290' and ran back to bottom. Average drag 5-10k Ibs. Drilled 12 ~" hole ITom 5209' to 6327'. 06-24-2001 - Drilled 12 ~" hole from 6327' to 6442'. Pull out of hole for new bit. Run in to shoe. Cut and slip drilling line. Run in to 6370' and wash to bottom at 6442'. Drill 12 1,4" hole from 6442' to 6661'. 06-25-2001 - Drilled 12 1,4" hole from 6661' to 8800'. Note: at 7850' allowed hole angle to drop naturally without sliding, instead of planned angle drop from 8750'D. 06-26-2001 - Drilled 12 ~" hole from 8800' to 9400'. Wiper tripped to 6300'. Encountered numerous tight spots over the interval 7200' - 6450', but did not have to back ream. Tripped in to bottom with no problem. Drilled to 9423' where drilling was temporarily suspended while circulating out high trip gas - peaked at 6400 units and fell back to 1300 units before drilling was resumed. Directional drilled 12 ~"hole from 9423' to 9725'. Hole angle was dropped from 20° to 12° while maintaining a heading of approximately 284°. 06-27-2001 - Drilled 12 1,4" hole from 9725' to 10104' - intermediate hole TD. Circulate bottoms up and pull out of hole to run wireline logs. I I I I I I I I I I I I BP Exploration - Northstar NS13 Daily Summary 06-28-2001 - Finish laying down BHA #4. Log with Schlumberger. First log would not pass below 5945'. A total of 4 attempts were made to pass through obstruction. The logging tools were pulled and a rubber extension and 3 bottom stand-offs were changed ttom 9" to 6". The logging tools were run back in with no problems. Schlumberger ran 2 RFT runs. Prepared to test BOPs. During the process of draining the stack and moving the liquid to the G&I approximately 40 gallons of fluid were leaked. The fluid was cleaned up and disposed of 06-29-2001 - Rig up and test BOP's. Run in hole for a clean out wiper run. Circulate and condition mud. Maximum gas of 4245 units for trip gas. Pull out of hole. 06-30-2001 - Pull out of hole with BRA #5. Rig up and run 9 5/8" casing. Hole started taking fluid on last 25 stands. 07-01-2001 - Continue to run in with 95/8" casing, wash to bottom. Circulate and condition mud. Gas maxed @ 1115 units. Pump cement as per well plan. Install 9 5/8" pack off, test to 5000 psi. Pumped 198 barrels of9.8 down 13 3/8" x 95/8" annulus. Preparing to pick up BRA #5 and run in hole. 07-02-2001 - Make Up BHA #5. Run in hole, circulate and condition mud. Test casing @ 3000 psi for 30 min, passed. Clean cement from 9814 to 9997. Test casing to 3000 psi for ten min. Drill out float equipment ttom 9997 to 10079. Wash and ream from 10079 to 10104. Circulate and condition mud for leak off test. Perform leak off test, 15 ppg. Circulate to Raise mud weight to 11.3 ppg. Continued drilling ttom 10124 to 10295. Repair mud pumps. Continued drilling from 10295 to 10411. 07-03-2001 - Continue drilling fÌ"om 10411' MD to 11490' MD. Circulate bottoms up. Make a wiper trip back to shoe, no problems. Trip back to bottom. Circulate bottoms up. Bottoms up maximum gas were 602 units. WELL TO BE CONTINUED AFTER SUMMER HIATUS. 2 Time (hrs) 06-14-2001 2100-2400 BP Exploration - Northstar NS-13 Daily Operations (I.A.D.C.) Elapsed Code Operations Breakdown Time 06-15-2001 0000-0500 5.00 0500-1700 12.00 1700-1800 1800-1900 1900-2200 2200-2300 2300.2400 06-16-2001 0000-0100 0100-0200 0200-0300 0300-0400 0400-0430 0430-0700 0700-1100 4.00 1100-2400 12.50 3.00 1.00 21 1.00 21 3.00 14 1.00 21 1.00 21 1.00 1.00 1.00 1.00 0.50 2.60 06-17-2001 0000-1700 17.00 1700-1800 1.00 1800..2400 6.00 06..18-2001 0000-0100 0100-0300 0300-0530 I I 0530.Q730 0730-0930 0930-1200 1200-1300 1300-1430 1430-1530 I 1530..2130 2130-2200 I 2200-2400 I 06-19.2001 0000-0100 0100-0130 0130.Q430 0430-0700 0700.Q830 0830-1200 1200-1330 1330-1400 1.00 2.00 2.50 2.00 5 2.00 6 2.50 6 1.00 12 1.50 12 1.00 21 6.00 12 0.60 12 2.00 12 1.00 21 0.50 12 3.00 12 2.50 12 1.50 12 3.50 12 1.60 21 0.60 12 1 Release rig from NS 27 at 21:00 hrs on June 14, 2001. Move rig from NS-27 to NS-13 1 1 Finish moving rig from NS-27 to NS-13. Rig up supply lines between pipe rack and rig. Test G&I injection line to 4500 psi - OK. Charge supply lines with fluids into rig. Mix Spud Mud. Build berms around rig & service complex. Start nippling up hyril on diverter spools. Spot and rig up Schlumberger wireline unit and sheaves to run Gyro. Spot rig mats and build forklift ramp. Hold pre-spud meeting with Nabors night crew and service companies. Hold pre-spud meeting with Nabors day crew. Finish rigging up riser between Hydril and flowline. Install and tighten turnbuckles on hyril. Install mousehole. Finish rigging up floor and pick up BHA. Bring miscellaneous BHA X-O's and tools to rig floor. Pick up 13 3/8" hanger and drift through Hyril and riser spools 6 8 20 5 6 6 6 2 Make up BHA #1 with 16" bit, X-O, stab, DC and HWDP. Install derrick safety bar. Hang Schlumberger wireline sheaves for Gyro. Break circulation and pump thru surface equipment and check for leaks. RIH and tag ice plug at 55'. Drill through ice plug 10-15' thick. POOH to HWDP. Continue picking up reaming DC's and jars. RIH with HWDP - Tag gravel at 156'. Wash down to 229'. Circulate. (Note: Gyro at 100' drift 0.7C1 and Az 143°, 150' drift 1.2° and Az 145°, 200' drift 1.3° and Az 1400) POOH with HWDP. Make up BHA #2 which included orienting sub, MWD and jars. Drill 16" hole from 229' to 1105'. Note: Gyro at 270' 0.4° and Az 145.8°, therefore decision made not to run Gyro's and used MWD surveys 2 Drill 16" hole from 1105' to 2824' 6 Starting to see some fill on bottom. Pull off bottom and circulate Hi-Vis sweep. 2 Drill 16" hole from 2824' to 3175'. 2 5 6 Drill 16" hole from 3175' to 3215'. Pump Hi-Vis sweep and circulate out. Wiper trip to HWDP. Tight spot at 3108' - maximum overpull 30k Ibs. RIH slick - no problems and no fill on bottom. Circulate 2 bottoms t,lp. Drop Gyro and pump down slowly. Pump slug. POOH to BHA - no problems. Rack back BHA in anticipation for drilling NS-14 surface hole. Clean rig floor. Make up 13 3/8" casing hanger to landing joint. Lay down hanger joint and remove hanger back to pipe shed. Rig up casing running tools. PJSM on running 13318" casing. Perform a top drive and derrick visual inspection for loose bolt, pins, etc. No problems discovered. Run a total of 79 joints 13 3/8" 68# L-80 BTC. Float shoe 3197~63', float collar 3155.41', landing collar 3112.94' and ES cementer 1608.28'. Hole slick - no problems running casing to bottom. Make up casing hanger and two piece landing joints. Slack off and land hanger. Final pick up weight 275k Ibs, which includes 65k Ibs for top drive. Final slack off weight 220k Ibs, including 65k for top drive. Back out casing fill-up tool from top drive. The casing fill-up tool was resting on the tool push plate on top of the casing collar. At 22:15 hrs a Floorhand was screwing a lifting eye into the top of the fill-up tool. During the operation an injury occurred. The injured employee was taken to the North Star Medic. All drilling related activities were temporarily suspended, pending further evaluation. Finish accident review and hold PJSM for rigging down casing fill-up tool. Rig up cement head. Lay down fill-up tool. Rig up Halliburton cementing head and cementing hose. Circulate and condition mud prior to cementing. Pump 1st stage cement job. Lead - type L, 140 stks, 103 bbls, wt 10.5 ppg, yield 4.16. Tail- Premium G, 2% CaCI, 470 sks, 96 bbls, wt 15.9 ppg, yield 1.15. Displacement - 25 bbls sea water & 441.3 bbls mud at 10.0 bbls/min with full returns. Bump plug. Open ES cementer at 2200 esi. Circulate and condition mud between stages. Got -6 bbls from 1 stage cement job, after opening the ES cementer. Pump 2nd stage cement job. Tail- Permafrost E, 1853 sks, 716 bbls, wt 12.0 ppg, yield 2.17. displacement 26 bbls sea water 216 bbls mud at 8.0 bbls/min with full returns. Bump plug. Close ES cementer with 1600 psi. Check BPV's - OK. Develop procedure for rigging down Halliburton cementing head. Rig down Halliburton cementing head. BP Exploration - Northstar NS-13 Daily Operations (I.A.D.C.) Time (hrs) 1400-1500 1500-1530 1530-1630 1630-1730 1730-1930 1930-2300 2300-2400 Elapsed Code Operations Breakdown Time 1.00 21 0.50 21 1.00 21 1.00 21 2.00 21 3.50 21 1.00 6 Develop procedure for laying down landing joint. Hold planning meeting with all Drilling personnel concerning the revised forward plan from Anchorage offICe. Lay down landing joint. Clear rig floor area. Change from long to short bails. Change to DP elevators. Pick up joint on DP and wash out BOP's. Show / orient new rig crew personnel around rig while the investigation team conducted interviews. Lay down 16" BHA tool and MWD. [ 06-20-2001 0000-0100 0100-0230 0230-0300 0300-0430 0430-0530 0530-1000 1000-1100 1100-1130 1130-1200 1200-1430 1430-1600 1500-1630 I I 1630-2200 2200-2230 2230.2300 2300-2400 06..21..2001 0000-0100 0100-0130 0130..0330 0330-0430 0430-0600 0500-0630 0530-0600 0600-0630 0630-0800 0800-0900 0900..1000 1000..1400 I I I I 1400..1430 1430..1600 1600-1730 1730.2400 06-22..2001 0000-0730 0730..Q830 0830..1000 I 1000-1200 2.00 1200.2400 12.00 06-23..2001 0000..Q100 0100..Q130 0130..Q3oo 0300-1200 1200-2400 06.24-2001 0000..Q300 0300..Q330 0330-0630 0630..Q800 1.00 0.60 1.50 9.00 12.00 1.00 1.50 0.50 1.60 1.00 4.50 1.00 0.60 0.60 2.60 0.50 1.50 5.50 15 0.50 15 0.50 15 1.00 7 1.00 0.50 2.00 1.00 0.50 0.50 0.50 0.50 1.50 1.00 1.00 4.00 0.50 5 1.50 21 1.60 5 6.50 2 7.50 1.00 1.50 3.00 0.50 3.00 1.50 21 6 21 14 14 14 Walk around with new personnel. Lay down BHA from 16" hole section. PJSM Nipple down riser and diverter. Set riser on NS-14. Nipple up tubing head adaptor. Nipple up BOP - install choke and kill lines, turnbuckles and Koomey hoses. Install drilling sweep and valve. Function rams. Install master bushings and iron roughneck track. Grease choke valve manifold and clean rig floor. PJSM. Install test plug and fill lines. UA test rig crews. PJSM for testing BOP. Test BOP's 260 psi low for 16 min and 6000 psi high for 10 min. Detected leaks. Hold PJSM. Tighten stack, choke u..bolts, packing gland nuts on lockdown screws. Grease" HCR kill line. Continue with BOP test. AOGCC representative Jeff Jones waivered witness of test. PJSM - pull test plug and install wear ring. Back out test joint and lay down. Blow down mud lines and top drive. PJSM - Service top drive. 7 21 16 21 15 14 7 21 6 6 6 16 15 6 5 15 21 21 Service top drive and install mousehole. PJSM for making up BHA. Make up BHA #3 - orient MWD & motor. RIH. Wash down and tag ES cementer at 1608'. PJSM and test casing to 1000 psi for 5 min. Drill ou ES cementer and test casing to 1000 psi for 5 min. RIH to cement above landing collar. Wash down to 3166', to top of cement. Circulate and condition mud until MW "in" = MW "out" = 9.2 ppg. test casing to 2500 psi for 30 min - good test. Reviewed D1, D2 and D5 drills with rig crews. Perfonn D6 drill with crews. Blow down choke and kill lines. Drill cement and float track, collar, shoe and 30' of formation to 3245'. Note: Return mud badly clabbered from cement contamination. Circulate hole clean until MW "in" = MW "out" = 8.7 ppg. Perfonn FIT to 12.6 ppg EMW. Blow down choke and kill lines. PJSM. Displace well to new drilling fluid. Directional drill 12 W' hole from 3215' to 3593t. Build angle from 21° to 30°. 2 5 6 2 2 Directional drill 12 %" hole from 3593' to 4256'. Finished build at 3611'. Circulate Hi-Vis sweep and monitor well- static. Wiper trip to shoe at 3196' and RIH to bottom. Note: Stand 6 and 6 overpulled 30k Ibs, stand 7 swabbed but was clear after wipe through. Remainder of stand pulled OK. Drill 12 y,." hole from 4256' to 4510'. Drill 12 W' hole from 4510' to 5116'. Note; Slide 30' every 400' to stop 1/3°/100' dropping and 1/2°/100' walking tendencies. 2 Drill 12 W' hole from 5116' to 5209'. 6 Finish circulating Hi-Vis sweep - monitor well - static. 6 Wiper trip to 4290' and RIH to bottom. Maximum drag 25k Ibs, average drag 5..10k Ibs. Hole fill good. 2 Drill 12 Y.." hole from 5209' to 5781'. 2 Drill 12 %" hole from 5781 to 6327'. Sliding 25'/500' to arrest dropping and walking tendency. 2 Drill 12 Y.." hole from 6327' to 6442' 5 Circulate and monitor well. Pump slug. 6 POOH. Hole slick. No problems. 6 PJSM and lay down BHA #3. 2 BP Exploration - Northstar NS-13 Daily Operations (I.A.D.C.) Time Elapsed Code Operations Breakdown (hrs) Time 0800-0830 0.50 21 Download CDR and clean rig floor. 0830-1030 2.00 6 Pick up BHA #4. Orient MWD and motor. Change bend on mud motor from 1.5° to 1.16°. 1030-1100 0.50 21 Shallow test MWD and PJSM for picking up ADN and source. 1100-1200 1.00 21 Pick up ADN and load source. 1200-1400 2.00 6 RIH with HWDP and 5" DP. 1400-1600 1.00 21 PJSM for cut and slip drilling line. Man rideing tugger operation. 1500-1700 2.00 9 Cut and slip 102' drilling line. Inspect brakes and drawworks. 1700-1830 1.50 7 PJSM and service top drive and crown. 1730-2000 1.60 6 RIH from 3140' to 6370'. Hole slick and no problems encountered. 2000-2030 0.50 5 Wash down from 6370' to 6442'. 2030-2400 3.50 2 Drill 12 W' hole from 6442' to 6681'. 06-25-2001 0000-2400 24.00 2 Drill 12 W' hole from 6661' to 8800'. Note: at 7850' allowed hole angle to drop naturally without sliding, instead of planned angle drop from 8750'. 06-26-2001 [ 0000..0630 6.50 2 Drill 12 W' hole from 8800' to 9400'. 0630..0800 1.50 5 Circulate bottoms up and monitor well. Pump slug. 0800.1030 2.50 6 Wiper trip to 6300'. Encountered 6 tight spots over interval 7200' - 6450'. Able to work through without back reaming. 1030-1200 1.50 6 RIH to 9328' and wash to bottom. No hole problems. 1200-1300 1.00 2 Drill 12 Y4" hole from 9400 to 9423'. 1300.1330 0.50 5 Circulate out 6000 units gas down to 1300 units. 1330.2400 10.60 2 Directional drill 12 %" hole from 9423' to 9726'. Hole angle was dropped from 20° to 120 while maintaining a heading of approximately 2840. [ 06-27.2001 0000.1030 10.50 2 Directional drill 12 W' hole from 9725' to 10104' (TD Intermediate hole section). 1030-1230 2.00 5 Circulate hole clean. 1230-1300 0.50 6 Monitor well and POOH with 3 stands DP - monitor well - static. 1300-1800 6.00 6 Pump Dry Job. Blow down lines and POOH to shoe. 1800.1830 0.50 21 Monitor well and perform D.1 drill. 1830-2000 1.50 6 POOH. Have PJSM for laying down BHA. 2000..2130 1.50 6 PJSM and lay down Source and ADN. [ 2130.2400 2.50 6 Lay down BHA #4. 06.28..2001 0000..0100 1.00 6 Lay down tools and clean rig floor. 0100..0130 0.50 21 PJSM for rigging up Schlumberger. ( 0130..0230 1.00 11 Rig up wireline and logging tools. 0230-0600 2.50 11 RIH with PEX tool. Would not go past 5945'. Made 4 attempts. Landed at same depth. No problem picking up. 0500.0600 1.00 11 POOH with logging tool. Install longer rubber extension on end of tool. Change 3 bottom stand-offs from 9" to 6". 0600-1330 7.50 11 RIH with PEX tool. Log from 9960' to 1400'. POOH. 1330..2330 10.00 11 Rig up RFT - Log #2. Took 22 pressure samples from 9843' to 9677'. Took fluid samples at 9683' and 9761'. POOH with wireline and rig down Schlumberger. 2330-2400 0.50 21 Prepare to test BOP's. Rig up to drain stack through casing valve with rig 3" air pump. Had leak between [ G&I and rig. Approximately 40 gallons leaked, but were cleaned up and disposed of. 06.29-2001 0000.0030 0.50 15 PJSM on testing BOP's. [ 0030.0130 1.00 15 Pull wear bushing and install test plug. 0130-0230 1.00 15 Rig up to test BOP's. 0230-1030 8.00 15 Test BOP's and choke manifold as per BP policy. 1030-1130 1.00 15 Rig down test equipment and blow down choke and kill line. 1130-1230 1.00 7 Service top drive. I 1230-1330 1.00 6 Make up BHA. 1330-1730 4.00 6 RIH to 9926' - fill DP every 3000'. 1730-1830 1.00 3 Wash and ream to bottom - took weight 4 times while reaming to bottom. 1830-2100 2.50 5 Circulate bottoms up and condition mud. 2100-2400 3.00 6 Monitor well. POOH 2 stands and pump Dry Job. POOH. 06-30.2001 0000.0200 2.00 6 POOH to 133/8" casing shoe. 0200-0300 1.00 6 Monitor well and continue to POOH. 0300.0330 0.50 6 Monitor well and POOH with HWDP. 0330-0400 0.50 21 PJSM for laying down BHA #5. 3 BP Exploration - Northstar NS-13 Daily Operations (I.A.D.C.) Time (hrs ) 0400-0430 0430~OO 0600-0730 0730-0930 0930-2400 Elapsed Time 0.50 1.50 1.50 2.00 14.60 I 07..01-2001 0000-0200 2.00 12 0200-0430 2.50 5 0430..0830 4.00 12 0830-1030 2.00 12 1030-1200 1.50 12 1200-1230 0.50 21 1230-1400 1.50 21 1400-1930 5.50 21 1930-2200 2.50 21 2200-2400 2.00 6 07..02..01 0000-0100 1.00 6 0100-0400 3.00 6 0400-0730 3.50 6 0730..0800 0.50 5 0800..0900 1.00 15 0900-0930 0.50 21 0930-1100 1.50 21 1100-1230 1.50 21 1230-1300 0.50 5 1300-1330 0.&0 21 1330-1730 4.00 2 1730-2030 3.00 2 2030-2130 1.00 21 2130-2400 2.50 2 I I I I I I I Code Operations Breakdown 21 Clear rig floor. 21 PJSM - pump out stack with trash pump. Pull wear ring and install test plug. 14 Change upper pipe rams to 9 5/8" and test bonnet seals to 1000 psi. Pull test plug. 12 PJSM prior to running 9618" intennediate casing. 12 Run 9 518" casing. Hole started taking fluid on last 25 stands. Hole In excellent condition. Run 9 618", 47#, L-80 casing. RlU Landing joint and hanger. Break circulation. Shut down pump. Land casing. Set at 10083' MD. RlU cement head. Circulate capacity of casing. Had PJSM for cementing casing. Stablished circulation at 1 BPM and increased to 10 BPM. Mix and pump cement as per program. See cement report. Displaced cement with mud pumps. Pumped calculated strokes (96%) effICiency plus Yz shoe track ( 8392 ) strokes. Plug did not bump. HOWCO flow meter showed 2 bbls difference from rig pumps. Check floats. OK. RID landing joint, cement equipment, tongs, change bails and drain stack. Install 9 5/8" packoff. Test to 6000 psi. Rig down packoff running tool. R/u lines to bullhead mud down 9 5/8 x 133/8 annulus to flush annulus. Pumped 192 barrels of 9.8 mud out of critical path. Remove 9 5/8 rams. Install VB rams. Test to 5000 psi. Slip and cut 100' of drilling line. Service top drive and rig. Lay down 8" BHA. Finish laying down BHA. M/U BHA #6. RIH to 9814'. Tagged cement. Circulate and condition mud. Test casing to 3000 psi for 30 minutes. Perfonn D-5 drill. Drill cement from 9814' to Float collar at 9997'. Test casing to 3000 psi for 10 minutes. Drill out float equipment, cement and 20' of new hole to 10124'. Circulate and condition mud for LOT. Conduct LOT to 15.0 ppg EMW with 9.8 ppg mud. Circulate and condition mud. Raise mud weight to 11.3 ppg. Drill from 10124' to 10295', Repair #2 mud pump. Drill from 10295' to 11490'. No hole problems. 4 sperry-sun DRILLING SERVICES Show Report Well Name: NS-13 Location: Northstar Area Operator: BP Exploration Alaska Report Prepared By: Wayne Hermanson Report Delivered To: Ken Lemley 5890 to 5980 ft 5545 to 5624 ft Show Report No. 1 Dateffime: 24-Jun-01 Depth (MD) (TVD) Mud Chlorides (ppm) = Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 % Depth 5912 ft Gas Units 1067 Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 101714 8324 93390 C1/C2 = 76.5 C2 1327 107 1220 C1/C3 = 1037.7 C3 115 25 90 C1/C4 = 8490.0 C4 33 22 11 C1/C5 = 8490.0 C5 29 18 11 5970 ft Gas C1 C2 C3 C4 C5 Flowline ppm 25873 285 48 29 20 Production Analysis: C1 C2 1000.0 NPH ..."" ...'" ..."" ... 100.0 Suction ppm 8324 107 25 20 15 Non-Producible Hydrocarbons 299 Mud Chlorides (ppm) = Gas ......~"'- Show 10.0 --- ppm Hydrocarbon Ratios 17549 C1/C2 = 98.6 011 178 C 1/C3 = 763.0 ---..-- 23 C1/C4 = 1949.9 --- NPH 9 C1/C5 = 3509.8 1.0 5 Non-Producible Hydrocarbons := = I LITHOLOGY: J~89~-5930') Siltstone: fight grey to ~ght tan amorphous to sub blocky,___- occasional wispy carbonaceous laminations, very tuffaceous, sandy laminations, grading to very fine grained sandstone in part, soft to rarely firm, 10% pale yellow pin point fluorescence, instantañëõus pale blue yellow ~-- on dry sample. (5960'-5980') Siltstone: light g.r.ey to light tan, amorphous to'sub blockŸ,- occasional wisPY carbonaceous lamlnations, very tuffaceous, very glauconitic, sandy laminatlons, grading to very fine grained sandstone in part, soft to very firm~ slightly calcareous in part, 20% bright yellow-iiuorescence, slow to moderat.!.Eale yellow cut. - r [ ISHOW EVALUATION: Evaluate section for probable production as indicated by the plotted curve within the following: a. 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 ClIC2 ratio falls low in the oil section, with the C lIC4 ratio high in the gas section, the zone is probably non-productive. r Since the majority of the gas breakdown is methane the Pixler plot indicates an unproductive gas zone. If a steam still could be run a better evaluation would be possible. No mud samples were caught over the intervals, therefore a steam still analysis is not possible. c. If any ratio (C l/C5 excepted if oil mud is used) is lower than a preceding ratio, the zone is probably non.productive. r The zone was evaluated because of the anomalous fluorescence that has not been seen on any of the wells to date. The resistivity log should be checked closely and future wells need mud samples cought over this section. I I I I I sperry-sun DRILLING SERVICES Show Report 7185 to 7225 ft 6668 to 6703 ft Show Report No. 2 DatelTime: 25-Jun-01 Well Name: NS-13 Location: Northstar Area Operator: BP Exploration Alaska Report Prepared By: Wayne Hermanson Report Delivered To: Ken Lemley Depth (MD) (TVD) % Depth 7251 ft Gas Units 657 Mud Chlorides (ppm) = Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 61321 11204 50117 C 1/C2 = 32.8 C2 1835 305 1530 C1/C3 = 963.8 C3 117 65 52 C1/C4 = 343.3 C4 220 74 146 C 1/C5 = 634.4 C5 110 31 79 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 C1 C2 1000.0 I """" ~ I ~ --- I .,~ / / ..,."" ..,.....- ,..- 1- -I I ~ .. ... .. --.. ...---- .....~" -- -- .- - l llM"''''- ----- -- -- ---- -- NPH 100.0 5970 ft Gas Non-Producible Hydrocarbons 299 Mud Chlorides (ppm) = Gas Show 10.0 ppm Hydrocarbon Ratios C1/C2 = 011 C1/C3 = C1/C4 = NPH C1/C5 = 1.0 Non-Producible Hydrocarbons Flowline ppm Suction ppm C1 C2 C3 C4 C5 I: Production Analysis: I LITHOLOGY: Siltstone: light to medium grey, blocky, amorphous in part, clayey, carbonaceous micro specks, tuffaceous in part, micro-micaceous I slightly calcareous, predominantly soft to occaSionally firm, rarely hard, 5% dull yellow fluorescence, very slow pale blue cut on dry sample. - - Evaluate section for probable production as indicated by the plotted curve within the following: -----'- -------_.._--_.~-- a. Productive dry gas zones may show only CI, but abnormally high C I only shows are usually indicative of salt water. ---- ---.... ------ -.-----...- b. If the C l/C2 ratio falls low in the oil section, with the C l/C4 ratio high in the gas section, the zone is probably non-productive. -- --- ISHOW EVALUATION: The Pixler plot indicates a non productive zone as indicated by negitive slope with C1/C4 ratio. c. If any ratio (C lICS excepted if oil mud is used) is lower than a preceding ratio, the zone is probably non-productive. Sample indicate very poor porosity. This zone would be poor for gas production. I I I I I I I I I sperry-sun DRILLING SERVICES Show Report 7185 to 7225 ft 6668 to 6703 ft Show Report No. 2 DateITime: 25-Jun-01 Well Name: N5-13 Location: Northstar Area Operator: BP Exploration Alaska Report Prepared By: Wayne Hermanson Report Delivered To: Ken Lemley Depth (MD) (TVD) % Depth 7251 ft Gas Units 657 Mud Chlorides (ppm) = Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 62403 11204 51199 C1/C2 = 20.6 C2 2792 305 2487 C1/C3 = 237.0 C3 281 65 216 C 1/C4 = 52.2 C4 1055 74 981 C 1/C5 = 60.2 C5 882 31 851 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 C1 C2 1000.0 NPH .." ,," ...'" 100.0 Non-Producible Hydrocarbons Mud Chlorides (ppm) = 299 Gas Flowline ppm Show ppm Suction ppm 10.0 Hydrocarbon Ratios C1/C2 = C1/C3 = C1/C4 = C1/C5 = --j C1 C2 C3 C4 C5 '= Oil .. --......- NPH 1.0 = Production Analysis: Non-Producible Hydrocarbons LITHOLOGY: Siltstone: light to medium grey, blocky, amorphous In part, clayey, - - carbonaceous micro specks, tuffaceous In part, micro-micaceous, slightly calcareous, predominantlY soft to occasionally firm I rarely hard, 5% dull yellòw fluorescence, very slow pale blue cut on dry sample. -- -- -- Evaluate section for probable production as indicated by the plotted curve within the following: ------------ a. Productive dry gas zones may show only Cl, but abnonnally high C 1 only shows are usually indicative of salt water. -- -- -- -------" b. If the ClIC2 ratio falls low in the oil section, with the Cl/C4 ratio high in the gas section, the zone is probably non-productive. ----- -------~-- ISHOW EVALUATION: The Pixler plot indicates a non productive zone as indicated by negitive slope with C1/C4 ratio. c. If any ratio (C lIC5 excepted if oil mud is used) is lower than a preceding ratio, the zone is probably non-productive. Sample Indicate very poor porosity. This zone would be poor for gas production. The same interval analzed with steam still readings still indicates a negative slope, and therefore a poor candidate for gas production. --- I sperry-sun DRilLING SERVICES Show Report Well Name: NS-13 Location: Northstar Area Operator: BP Exploration Alaska Report Prepared By: Wayne Hermanson Report Delivered To: Ken Lemley 9040 to 9160 ft 8342 to 8455 ft Show Report No. 3 Date/Time: 26-Jun-Q1 Depth (MD) (TVD) Mud Chlorides (ppm) = 36000 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 % Depth 9060 ft Gas Units 1880 C1 C2 Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 147808 7293 140515 C 1/C2 = 11.3 C2 13079 638 12441 C1/C3 = 32.8 C3 4570 283 4287 C1/C4 = 91.9 C4 1659 130 1529 C 1/C5 = 286.2 C5 577 86 491 Depth 9140 ft Gas C1 C2 C3 C4 C5 Flowline ppm 98371 8776 3364 1452 527 1000.0 NPH 100.0 Non-Producible Hydrocarbons 1242 Mud Chlorides (ppm) = 36000 Gas Suction ppm 7293 638 283 130 86 Show ppm 91078 8138 3081 1322 441 10.0 =: Hydrocarbon Ratios C1/C2 = 11.2 C1/C3 = 29.6 C1/C4:: 68.9 C1/C5:: 206.5 NPH 1.0 - Oil I Non-Producible Hydrocarbons I I I I I I LITHOLOGY: Siltstone: light to medium grey, blocky, laminated, clayey, micromicaceous in part, carbonaceous micro specks, tuffaceous in part, predominantly soft to occasionally firm, grading to ultra fine grained sandstone, trace dull -..-- yellow fluorescence, no cut. Evaluate section for probable production as indicated by the plotted curve within the following: ---- a. Productive dry gas zones may show only Cl, but abnormally high C 1 only shows are usually indicative of salt water. .--.....--- ------------- ------------- -- b. If the Cl/C2 ratio falls low in the oil section, with the C 1/C4 ratio high in the gas section, the zone is probably non-productive. -- ISH OW EVALUATION: ------- The Pixler plot indicates a productive gas zone. Sample indicate very poor porosity. This zone would be poor for gas production. C. If any ratio (C lIC5 excepted if oil mud is used) is lower than a preceding ratio, the zone is probably non-productive. sperry-sun Well Name: NS-13 Location: Northstar Area DRILLING SERVICES Operator: BP Exploration Alaska Show Report Report Prepared By: Wayne Hermanson Report Delivered To: Ken Lemley % Depth 9060 ft Gas Units 1880 Mud Chlorides (ppm) = 36000 Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 27633 196 27437 C 1/C2 = 3.4 1000.0 C2 8147 172 7975 C1/C3 = 3.3 C3 8568 351 8217 C 1/C4 = 4.8 NPH C4 6156 491 5665 C 1/C5 = 8.5 C5 3688 459 3229 100.0 Non-Producible Hydrocarbons 9140 ft Gas 1242 Mud Chlorides (ppm) = 36000 Gas I Flowline Suction Show 10.0 ppm ppm ppm Hydrocarbon Ratios C1 18890 196 18694 C1/C2 = 3.8 011 I C2 50.44 172 4872 C 1/C3 = 3.9 C3 5099 351 4748 C1/C4 = 5.5 NPH C4 3876 491 . 3385 C 1/C5 = 9.3 1.0 C5 2476 459 2017 I Production Analysis: Non-Producible Hydrocarbons I LITHOLOGY: Depth (MD) (TVD) 9Ö4Ö to 9160 ft 8342 to 8455 ft Show Report No. ass DateITime: 26-Jun-01 C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 -- ..."" ........... ..."" - -- - - . - - -- _.......-- - - ~ '---- - - -- - ...-- -- -- ~lItstone: ligh~ to m~dium ~~~~~ockYI laminat!~1 clayey, mic~mic~eous in part, carbonaceous micro specks, tuffaceous in part, predominantly soft to occasionally firm, grading to ultra fine grãiñed sandstonë,t;ace dull yellow fluoresëënce, no cut. --- .---- Evaluate section for probable production as indicated by the plotted curve within the following: ---.- ---'- --------.- a. Productive dry gas zones may show only CI, but abnonnally high C I only shows are usually indicative of salt water. ---- .--- ----- --------- ---- b. If the Cl/C2 ratio falls low in the oil section, with the C lIC4 ratio high in the gas section, the zone is probably non-productive. I ----- -'-- SHOW EVALUATION: I The Pixler plot indicates a productive gas zone. I Sample indicate very poor porosity. This zone would be poor for gas production. c. If any ratio (C lIC5 excepted if oil mud is used) is lower than a preceding ratio, the zone is probably non-productive. The steam still analysis indicates that this zone could be an oil producer. Limited porosity in this zone still makes this zone poor for oil production. -------- I I sperry-sun DRilLING SERVICES Show Report Well Name: N8-13 Location: Northstar Area Operator: BP Exploration Alaska Report Prepared By: Wayne Hermanson Report Delivered To: Ken Lemley ( % Depth 9663 ft Gas Units 4358 Mud Chlorides (ppm) = 36000 Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios ( C1 374878 8415 366463 C 1/C2 = 14.8 C2 25808 1037 24771 C 1/C3 = 64.2 C3 6461 756 5705 C1/C4 = 223.5 ( C4 2165 525 1640 C1/C5 = 714.4 C5 805 292 513 ( Non-Producible Hydrocarbons 9692 ft Gas 2928 Mud Chlorides (ppm) = 36000 I Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 291473 8415 = 283058 C1/C2 = 15.5 I C2 19317 1037 18280 C1/C3 = 69.0 C3 4860 756 4104 C1/C4 = 253.6 C4 1641 525 1116 C 1/C5 = 972.7 C5 583 292 291 I Production Analysis: Non...Producible Hydrocarbons I LITHOLOGY: Sandstone: light to medium brown, very fine to fine grained, angular, to --- - --...- sub angular, well sorted, friable to moderately well cemmented, siliceous cement, predominately quartz, tr pyrite and glauconite, dull yellow ----- fluorescence, vëiy slowwhiteyellow cut, oil stain, no odour. --- -- I -- ------- ---- I ISHOW EVALUATION: I The Pixler plot indicates a productive gas zone. I Samples indicate fair porosity along with fluorescence and cut. This zone is rated as fair for gas production. 1000.0 NPH 100.0 NPH 1.0 9650 to 9710 ft 6924 to 8982 ft Show Report No. 4 DatelTime: 27-Jun-01 Depth (MD) (TVD) C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 cs Gas 10.0 Oil Evaluate section for probable production as indicated by the plotted curve within the following: a. Productive dry gas zones may show only CI, but abnonnally high C I only shows are usually indicative of salt water. b. If the ClIC2 ratio falls low in the oil section, with the C 1/C4 ratio high in the gas section, the zone is probably non-productive. c. If any ratio (C lIC5 excepted if oil mud is used) is lower than a preceding ratio, the zone is probably non-productive. I sperry-sun Well Name: NS-13 Location: Northstar Area DRILLING SERVICES Operator: BP Exploration Alaska Show Report Report Prepared By: Wayne Hermanson Report Delivered To: Ken Lemley % Depth 9663 ft Gas Units 4358 Mud Chlorides (ppm) = 36000 Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 2998 196 2802 C 1/C2 = 4.4 C2 804 172 632 C1/C3 = 5.3 C3 880 351 529 C1/C4 = 9.0 C4 804 492 312 C1/C5 = 28.6 C5 557 459 98 Non-Producible Hydrocarbons 2928 Mud Chlorides (ppm) = 36000 Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 23614 196 = 23418 C1/C2 = 3.9 C2 6115 172 CII 5943 C1/C3 = 3.8 C3 6583 351 =:I 6232 C1/C4 = 4.4 C4 5763 492 = 5271 C1/C5 = 6.7 C5 3956 459 3497 Production Analysis: Non-Producible Hydrocarbons I LITHOLOGY: I I I I I _Sandstone: light to medium brown, very fine to fine graine~ angular, to sub angular, well sorted I friable to moderately well cemmented, siliceous cement, predominateiy quartz, tr pyrite and glauconite, dull yellow fluorescence, very siôw white yellow cut, 011 stain, no odour. -=------ I I ---- -...-- ------- --- I SHOW EVALUATION: I The Pixler plot indicates a productive oil zone. Samples indicate fair porosity along with fluorescence and cut. This zone is rated as fair for oit production. I -~--- 1000.0 100.0 NPH 1.0 9è5ö to 9710 ft 8924 to 8982 ft Show Report No. 4SS DateITime: 27-Jun-01 Depth (MD) (TVD) C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 NPH " " " , -- ./ --- .----. /-- -- -- -- ...- ....... ~ .... -- ------ ----- -- ---- Gas 10.0 Oil Evaluate section for probable production as indicated by the plotted curve within the following: a. Productive dry gas zones may show only CI, but abnonnally lù.gh C 1 only shows are usually indicative of salt water. b. If the Cl/C2 ratio falls low in the oil section, with the Cl/C4 ratio high in the gas section, the zone is probably non-productive. c. Ifany ratio (ClIC5 excepted if oil mud is used) is lower than a preceding ratio, the zone is probably non-productive. sperry-sun DRilliNG SERVICES Show Report Well Name: NS-13 Location: Northstar Area Operator: SF' Exploration Alaska Report Prepared By: Wayne Hermanson Report Delivered To: Ken Lemley 1 % Depth 9764 ft Gas Units 1812 Mud Chlorides (ppm) = 36000 Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 149020 8415 140605 C1/C2 = 13.3 C2 11640 1037 10603 C 1/C3 = 56.9 C3 3227 756 2471 C1/C4 = 218.7 C4 1168 525 643 C1/C5 = 1480.1 C5 387 292 = 95 I Non-Producible Hydrocarbons Mud Chlorides (ppm) = 36000 9782 ft Gas 3073 I Flowline Suction Show ppm ppm ppm Hydrocarbon Ratios C1 239848 8415 == 231433 C 1/C2 = 13.2 C2 18533 1037 == 17496 C1/C3 = 52.6 C3 5139 756 "" 4383 C1/C4 = 175.6 C4 1843 525 "" 1318 C 1/C5 = 630.6 C5 659 292 367 Production Analysis: Non-Producible Hydrocarbons I LITHOLOGY: I I Sandstone: light to medium brown, very fine to fine grained, occasionally gråding to siltstone, angular to subãngular, well sorted, friable to moderately -- - --- well cemented, siliceous cement, predominantly quarts, tr~ce glauconite and pyrite, dull yellow fluorescence, very slow white yellow cut I no odor. ------ I I ----- ------ -- --~ ISHOW EVALUATION: I The Pixler plot indicates a productive gas zone. Samples indicate fair porosìty along with fluorescence and cut. This zone is rated as fair for gas production. There was no steam stili samples caught for this interval, but it appears to be much the same as the previous interval that showed the zone to be an oil producer when analyzed with the steam still. ----- 1000.0 NPH 100.0 NPH 1.0 9755 to 9111Ö ft 9026 to 9082 ft Show Report No. 5 DateITime: 27-Jun-01 Depth (MD) (TVD) C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 Gas 10.0 --- 011 ...----- Evaluate section for probable production as indicated by the plotted curve within the following: a. Productive dry gas zones may show only C I, but abnonnally high C I only shows are usually indicative of salt water. b. If the ClIC2 ratio falls low in the oil section, with the CI/C4 ratio high in the gas section, the zone is probably non-productive. c. If any ratio (C lIC5 excepted if oil mud is used) is lower than a preceding ratio, the zone is probably non-productive. r I I I I -i... "..~~~..:~"::r;.~;;,~~t..:,\:",.).::,,:¡~ ~"'~I:: ':~=.~ .. :;;".. ~. 'I" ~.. :.~...:,p.'. ,. ........ ,...: ~',:. '.ì :.,: :".\ sper'r'v-sun Customer: Well: Area: Lease: Rig: Job No.: BP Alaska Northstar NS 13 North Slope Northstar NS 13 Nabors 33E AK AM 11103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: .'" .' 1 6/16/01 1121 885 Drilling Paul Lockwood . -- .- .. ...¡..", ¡":oJ;ti,~~~'It.~~'~~\W~W~~~~:,'i~:t.:t..:Ù"'~1't;j~þ¿;'1~~~;)~~. .:),"~I, ,(",:",-..:j¡f".:",,~-,~"I, ,..,',:..~....!i\\',~;~"Jt,'-,.- . RO.P. Gas" Temp Out 24 hr Max ftlhr @ units @ deg F @ 1041 ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres Pump and Flow Data 100 spm DH flow 100 spm Total flow spm AV @ rsr 1000 psi AV @ DC <~ "'~ ~1:t -:-'i~ ?'? : ~ ..! -'" ~ .~! - gpm 1~ 710 gpm~j fpm ..;1 ?~ - fpm ~~ ~;,ç:~Jr9~ii',ff~~~¡~~;r.1lt;:';:,:. :" "¡~'~ ft ft ft units - ppg units - ppg units ppg Connection Gas and Mud Cut ft units - ppg ft units -ppg ft units ppg ft ft ft -" Gas during after - -- --- . - "_. - - - - --- gJ:!l- L... L::.I_~~___-_? e__~ '1- I_~__~§ Mudlogger's Morning Report Current 91 ftlhr 0 units 60 Deg F 24 hr Avg 138.1 ftlhr ( 0 unit~ ( ( 403 0 - ,........ -_.........~~ ..:..--.¡........."""..I..~"'.J., \~ Mud Wt In Mud Wt Out 9.00 ppg Visc 65 secs API tilt 5.4 ml HTHP 0.0 ml Mud Wt at Max Gas ~ppg 9.30 ppg PV 21 cP YP 34 Ibs/100ft2 Gels 13 \ 21 Ibs/100ft2 pH 9.3 Sd 0 % - - -- - - ~:\1. ,"" 11;~:~I"~\~~t~jt~~~~~~~~'~\~~~'~.i1~~¡ '~¡~~t~:~~;'~1~~)1!; "',~lt' ..: 1,".',~,":,r:,I.:. ;~13I,~~'.:.:.:.""~~?::~=~.::.~~:r~~~'~~~~,:'J,(:"""'~~':\~7,~~'~:~:,'~~G,,:~~"'~'.~~'~~~~,~~:,'::;:r~~:Z:I~:.:::FL~! . ~,' l, .,.' ,.'~:',,' ,'1"*'.\' ,..":' ï,: ,",i.~~:;7~:~f ,;.,~: ;~"1'?:~ 5/12 Type: GTX-CPSG1 Bit Size: 16 RPM: 40 Hrs. On Bit: 7.2 Jets: 20 \ 20 \ 20 \ 12 \ \ TFA: 1.0310 ------ Total Revs on Bit: Footage for Bit Run 885' I I [ " I I I I, . ", ;':,'I{~:\\,},,,,",:,i:f\t::I"<;'~:~<}i'~''t... !-:Ii,:~<¿,,":::',i,;\:,," .;.:'\':.'¡~I\';'!!;'r,'l-~l' " units -ppg units -ppg units ppg % Lithology Cgl Sst Ls Sh ---- -- -- -- 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: 10 % GRAV 50 % SD 40 % CLY % %LCM Drilling. Breaks Depth Drill Rate during oz. r. ...¡ ~, "'I~ .1'~~~r~;:.i.$.;~I;'~i$.~:~~:~C*~~~.:r.~~:;..~< 0 after before before to to 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Magnets not used Logging Engineer: Mark Lindloff / Wayne Hermanson , . . :~:: ":~,,:i;~~~j~j~:~~!;~:i;{.~:¿i~'~:tûi.Ú~.i\t¡il * 1 0000 units = 1 00% Gas In Air ~~ *'::'1~.~':-'~ -" :~:. ..:'I:~..~ ~i.,: ~;:;::~~~~i=~~.:; ';~Ii'''.~~. , , . .,' ~.: ,,'..,~." , ' 5pe!l""'~v-sun "- -- D A I L..L..I N G 5 e A V I c: e 5 -,-.- ----- ",- "-----'- ._~----- -, ,- ,-.._--,- -,--_.- Mudlogger's Morning Report .. ~,,-v.~'.-.~?S...',...... -, ,,,:jo,"~~~/o¡~"'.,- '.;.,:,. .,¡. , .;-'~ ..,..',' "~"" .":":._~~J,¡::f:"~'~:)~;~')~1:;.';'~J~.y:;}£-~~" ¡ ~ RO,P, Gas. Temp Out Mud Wt In Mud Wt Out ~,. . ~..'" ."",". Current 0 ft/hr 1 units 60 Deg F 24 hr Avg 152 ft/hr ( 14 unit~ ( ( "-, .~ )~¡,Jt1':~>~i":\;G;iì.ilB~~:;¡r)A1J¡t)ë;~' . ' Customer: BP Alaska Well: Northstar NS 13 Area: North Slope Lease: Northstar NS 13 Rig: Nabors 33E Job No.: AK AM 11103 ;;fØ'~13}t1'>::)~,~'!f~l~1f..~i~tr;'i~t:,;;;;;'ji¡:;t~~T,r,~~~~:'.0:," .,t,¡:~;~,';i~S;:1 , Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 2 6/17/0 1 3216 2094 Drilling Paul Lockwood .,-;"~"I:'''~'-in;tJ~, . '~~~~v-!.;O',,-\~..!i!~i.~1.'4,¡~\i.,~~~¡¡-;1k"".l';< ;i;~:~.~",i¡:';.*,!; ,;.: ~.~;,i~. .'.~;..'ë1" . 648 80 24 hr Max ft/hr @ units @ deg F @ 640 gpm :: gpm >¡~ fpm ~~G fpm.:~.¡ Pump and Flow Data 90 spm DH flow 90 spm Total flow spm AV @ rsr 1250 psi AV @ DC ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres '.~., .. 2272 2291 9.00 ppg Visc 65 secs API filt 7.8 ml HTHP 0.0 ml Mud Wt at Max Gas 9.00 ppg PV 14 cP YP 36 Ibs/100ft2 Gels 13 \ 18 Ibs/100ft2 pH 8.4 -- ''''':>Ii,ir~~U'~' ,~i1I~1o'~1tij¡\f,#;\!:I!S ¡~~~~':r¡;¡;~,~ ( ( . ( L ( ( ( Bit No.: 1 Wt On Bit Trip Depth: Short Trip Depth Tight Spots: \it"~!?r~'¡t¡;~;, "¡'¡':¡~W~ilW'~;~~1!-,"""''a''';'#...': ',: Type: GTX-CPSG1 Bit Size: 16 5/30 RPM: 60 Hrs. On Bit 21.2 Jets: 20 \ 20 \ 20 \ 12 \ \ TFA: 1.0310 ------ Total Revs on Bit Footage for Bit Run 3014 ft Trip Gas: ft Short Trip Gas: to Current Lithology: , 60 % Depth ,,:' . .:".~~?~:: ~.~~~:.:,>/.:,:.~/:(: .., ..,."" L,.,:'~:'.:i~~!§;~t~~I'.I~ ft ft ft units -ppg units - ppg units ppg to Mud Cut - ppg Trip CI: Mud Cut - ppg Short Trip CI: to Feet of Fill on Bottom: 7000 before to to ..- ~~..... ': ' , ":,;~'. "~~'~~i~~*'~~. ppm ppm ft CLY 40 %LCM % SO 0 % 0 % Connection Gas and Mud Cut ft units - ppg ft units - ppg ft units ppg ft ft ft units -ppg units - ppg units ppg Drill F/1121 T/3216 Drilling Breaks Drill Rate during Gas during after % Lithology Cgl Sst Ls Sh after before -- -- ---- -- -- -- -- ,~~I~::l~'~:;~~:~]rT.V~:f,~7\J;~:~~p.~,T:~~(?I,~,:~~1:::~?:.:,E2,.:.;:;0I':~:/. ':."~~~.~:r.~~., ';"-~~:~:';¡:'~"":::;',~I~'~ft' '>~"','r~"..'.~z:'~"":~.'i;',~','i:"t~,,~~ 'J ;,;+'~ ,'~ :"~'/' :~'." ',-~~~;\~^.,è~~~.":"".'~... ~.. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Magnets not used ".....':"';':.. ..' . '~:", . . .., '.. . .... ~ .. , ".. :.~: . . ,..~: . ..,...' 0 oz. '~~jj.' . ..- '1f.'I!:~~1\W:'!-~Z{ê;'¡.r.~il:r--~+¡#~"':::~;"i~r.,:'«':?~.i¡;~;~U::,i~.; ';';~. :;. .~ ;;~ ;~t~~ : ': ...~.. "..~,~ 24 hr Recé !.~:! ~, * 10000 units = 100% Gas In Air ~ ::!~ Logging Engineer: Mark Lindloff 1 Wayne Hermanson , , ,." : r~' '.. ".,'; ~tt~~~~íi;;á¡j'tt;i... ~~~~~'~'{,;,:.' I I ~ ~ .'." '.. l'i]!;:~:: ,..::~'.\ \Î ~ i?'.~'''~::' I;;: ¡'l~f;¡!\:1"'?~';"!::'.;q.~ ê":~ ~.'::" ,~::. . ,\~:: .~.~; ',>. " ..' sper'rv-sun ---------.-.. -~ --.-...-. .h_. _._--- -- . C A I LL I N G 5 e A V I c: e 5 -------- - ------'--------'--~- Mudlogger's Morning Report .' }.. .~ '. \ .. ~f ,a', ,:. :'.....~'r1 .":.:~. Customer: Well: Area: Lease: Rig: Job No.: .':,s~;~~.Wtt", I .f:':~);:';'~;":;',:,:\,""~;f-¥J':'~;l.':'.~I\::":;.:,'~;,.~ ,c','~ .t, ~~::''¡;';I:.;~'<:I-. " .i~\":\,,;:":;i~~~;~"'~FPi'¡'- .' ~ ~ . I I I I I I I I BP Alaska Northstar NS 13 North Slope Northstar NS 13 Nabors 33E AK AM 11103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 3 6/18/01 3216 0 Cementi ng Paul Lockwood ~ Bit Size: Hrs. On Bit: Trip Depth: Short Trip Depth Tight Spots: 3216 ft Trip Gas: ft Short Trip Gas: CLY 40 i¥!'~~ . 1~:\'~~.;t\~~,...;t:;:,- ~~~f.1;*~.Y",,:..:.~:...,:~> ;~~';';:~"':'. ... ..:. w~, ~ { '~;' Current 0 0 60 24 hr Avg 24 hr Max Pump and Flow Data ft/hr 0 ft/hr ( 0 ft/hr @ 0 ) Pump 1 0 spm DH flow units 9 u n it~ ( 62 units @ 3216 ) Pump 2 0 spm Total flow 0 Deg F ( deg F @ ) Pump 3 spm AV @ rsr Pump Pres 0 psi A V @ DC ft ft ft units -ppg units -ppg units ppg R.O.P. Gas. Temp Out Mud Wt In Mud Wt Out 9.00 ppg Visc 63 secs API tilt 7.8 ml HTHP 0.0 ml Mud Wt at Max Gas - - 9.00 ppg PV 16 cP YP 40 Ibs/100ft2 Gels 21 \ 24 Ibs/100ft2 pH 8.2 -- þ' ..~~'5¡,¡;~~'~~~i~ Type: RPM: to 60 % Jets: \ --- Total Revs on Bit: \ \ TFA: --- Footage for Bit Run Current Lithology: Depth 62 7000 ppm ppm ft before to to Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: to % % %LCM SD 0 % 0 Connection Gas and Mud Cut ft units - ppg ft units - ppg ft units ppg Drill Rate during . Logging Engineer: Mark Lindloff / Wayne Hermanson ft ft ft units -ppg units - ppg units ppg Drilling Breaks after Gas during after % Lithology Cgl Sst Ls Sh before ---- ---- --- ---- }-~ .~~~}~t1~:~:~iS~~~*::ti?~.:~::~..:r.'. ~ :~} .i\:~:~~~~~rt~~~¡;~ .~".....". ,'..'.:-'.'.-1,.. ';~~~.'~f/Xf.~J~:f~~,Wi;[~~'!~~7D¥~.:":~'~I,~;~.~;¡;,.'.~ '\~.,/7!. )~." ':,'~.\'~~.\'~.".~>,'~\.'t::'~,.~~,:...".",~;.,.,:.V!. .-~, ''''".~' . oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Magnets not used ~'.::. .:: ~ ,'~" ",.:: ./"',. . .. . .' .,:.~:..:.~..~:¡'~~.~.¡...i~!~~;~t~~~~ tãï~:~~~~~~~~~~l~.~~~i::t:~"~::;,:/:'.: . 0 * 1 0000 ~~]~1.~:~~ .'. . ~'~~)i~~:~'~~~'~~~~~ :~~:.~;~~;;:. -~'~"::~~.~;l~~'~ : ,; ~'::" ~:, ,'-. .:""~;'.~I":~£~'.r.'.~.:;::,¡.~:. .~~1~";,,,:'1~~=:=~~:.;.:': ...:.-.':-.~ ~.II".'';' ~,~ ~: ';-, . ~~ ~ .":; .~.~..;.;¡ ~i.:"'; :: ":"1 . spe...,,..,v- sun CR_!_~~~~_G _.~-$ R.~_Lr.::_.§_~ Customer: Well: Area: Lease: Rig: Job No.: I Mudlogger's Morning Report .,~;- ~~.: '~.':".:":'~~'4',':,'¿'~~,~,~1~ÀÍi~'~'",0I;~ - :..~ f Current 0 ftlhr 0 units 60 Deg F 24 hr Avg 0 ftIhr ( 0 unit~ ( ( R.O.P. Gas* Temp Out I ,'~.~~~~" .'j. . .î..'I.,t"":{.1:)".J.\~.~¡~ ~~ . BP Alaska Northstar NS 13 North Slope Northstar NS 13 Nabors 33E AKAM 11103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: " , 4 6/19/01 3215 0 Lay Down B HA#~ Paul Lockwood ~-..~~;.:'" 'j~;~¡-"c~~'.'~-.f~:~.t/~fJ.i¡~;::~;':I.!;i;:,,' ':'w'_~~'~~'~;."7""',:~':-(-"::'~','rj;,\':;:!1.",;;:'J.~::~'~c ..'.-' .. 0 0 24 hr Max ftIh r @ units @ deg F @ ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres -¡ø¡:.:~ ~1Ifi~~~ ' Pump and Flow Data 0 spm DH flow 0 spm Total flow spm AV @ rsr psi A V @ DC 0 ;.::;;' . ~~ Mud Wt In Mud Wt Out 9.00 ppg Visc 50 secs API filt ~ ml HTHP ~ ml Mud Wt at Max Gas ~ ppg ~/! 9.00 ppg PV 13 cP YP 27 Ibs/100ft2 Gels 14 \ 16 Ibs/100ft2 pH 8.6 Sd 0.25 % ,.,;~ ~~'Q;\" <," - - t . <"':'î'~"d;;ti."";:'fj~1 I Type: RPM: Bit Size: Hrs. On Bit: [ Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to I 60 % CLY 40 Current Lithology: 0 0 0 Jets: \ --- Total Revs on Bit: \ \ TF A: --- Footage for Bit Run 15000 ppm ppm ft Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: to % SD 0 % 0 % units - ppg units - ppg units - ppg Connection Gas and Mud Cut ft units - ppg ft units - ppg ft units - ppg ft ft ft f ft ft ft f [ Depth Drill Rate during before to to ':'I.'::.'\',~:~':~."~~'~:~,~.fTl1t~~Ç.;~F~I~:~IT.~~~',7;~;~Y.,,' .,.tj.~I" <'~~':I~~:~.Þ~~';t.' ,r?~~'Rr~';'f:.?'" 'f.,\¿'~:~~',~,,: " oz. 1~~.~~*~~!~~~~~~~~~~:f¡.'~~~;'.~~~~' ~ . , . ~: ~+~~)~:. ~.' ,;~~~"~~~l'~;:' . :~~:'~~'f~ ~ '.: ;.~~':~.~;: :l.~~~tSi:,;~':.~~;Øì;~'~~: Drilling Breaks after before f 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Magnets not used Gas during after %LCM units -ppg units - ppg units -ppg % Lithology Cgl Sst Ls Sh -- -- .. : ...~ ',. ;'", ',' ,~ . . . ,'..,'''' '~,:I',.~~. ,'.;~~~.tt:..~. 1~.:1!~~:i ~"'~"" ,'. ,':: \ .r'1':":~'~~~~~~'~'L~~'.' '<, _:.~' ~"4-:~~~q'~~.I':~', I . Logging Engineer: Mark Lindloff / Wayne Hermanson 0 ---- ---- -- -- "\~.. ):~ '.\;-j * 10000 units = 100% Gas In Air :1~ .~.:.~.. . ~-. ::~=e: :;'--; ',... \.'.;. ::'f.'-; ~~:;t;,:~;~}...:¡~f.~-:~:.';Y'.;" ,~.'?~~ ..' . ~ . .' <.; ... "".~':'",,~¡gt~\,::wœ¡í'.b"\! ~ <. Customer: Well: Area: Lease: Rig: Job No.: , ço. ..~~~::.",:'!\"i;,:~W.~.iitL~"';1:1;=~~~1&ìit~~:M;ë;~:I;'.<;~fi;.'i:::~~~I~\"~";;~"'~:';'t':' sperrv-sun ----- .. - ------,- _. -- - . - .. C A I L..L..I N G 5 e A VI c:: e 5 ----------'--------.-----'-'-.-----'--- Mudlogger.s Morning Report ~"'.",~,-".:' -1-,,' ..~~I\-,~." ~\I"~""'~': . ."1 ~ r"":"'" . > '1 ,...~t,~.~f~ . .- . , BP Alaska Northstar NS 13 North Slope Northstar NS 13 Nabors 33E AK AM 111 03 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 6 6/21/01 3575 360 Drilling Joe Polya - ãQ\i.~~ ::;.t:, ." , '",,~',"1:~':.... Current 24 hr Avg 24 hr Max R.O.P. 120 ft/hr 0 ft/hr ( 0 ft/hr @ 0 Gas. 10 units 5 unit~ ( 20 units @ 3449 I Temp Out 55 Deg F ( deg F @ I I I I " I ï;I"¡:~ \, I i,~,\,'..,.:.' :~~~ '-..:'::)} I I I ,!.",.,' . ,:;, ", ':""'~' ,,1:..::j~:~'J'~if, . ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres Pump and Flow Data 100 spm DH flow 100 spm Total flow spm AV @ rsr 1200 psi AV @ DC 700 - ;, .: ','~,~~',~' ..,:~'''f..~~. ?~~~'~";::'\~""~' J.., ~'",I,;,....,,:.;...,' ,.:,1 - ,.,1 .~:~~-'~~~::i>':::fj.';,,~~~H;~~.. ,.. , ~~~~~~, 9.00 ppg Visc 50 secs API tilt ~ ml HTHP ~ ml Mud Wt at Max Gas - ppg 9.00 ppg PV 13 cP YP 27 Ibs/100ft2 Gels 14 \ 16 Ibs/100ft2 pH 8.6 Sd 0 % -- Logging Engineer: Mark Líndloff / Wayne Hermanson .,~,',' '~~~~~~:CLli:::~':':¿~~~~,~~~='~~~:~::~~~',l~,:::~:,::~::.]::~~~'L}:.~':2:.~r~'~'.~~:52=~'~~~~~==~i:.~~~-,"~'~L~~~~:;~~~1:;~~=:=Jr:r:~\,~~,1:"'~"'";,,,' ~"'.':,.'CI~\~:,..'''',,'~f:, '" ,.'. . '... ......<.:.':~':~~.. Jets: 16 \ 16 \ 20 \ 20 \ \ TFA: 1.0060 ------ Total Revs on Bit: 0 Footage for Bit Run 0 Mud Wt In Mud Wt Out "~~';\"ì¡','~,\~ Type: MX-CS1 DT1 Bit Size: 12 1/4 RPM: Hrs. On Bit: 0.0 Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: 15000 ppm ppm ft to to Current Lithology: 60 % CLY 40 % %LCM SD 0 % 0 % units - ppg units - ppg units - ppg Connection Gas and Mud Cut ft units -ppg ft units - ppg ft units -ppg units -ppg units -ppg units - ppg ft ft ft ft ft ft Drilling Breaks after Gas during after % Lithology Cgl Sst Ls Sh Depth Drill Rate during before -- -- before ,,' to to -- -- ~',',""~,[':.~~7:~::~"r~~~~~1~:,.:t~~~.!A.~tii'~:~''~',~ ~:?1;...!\I::\I.';;,~~.,~., ?~'~..'-~~~2~.'~.:~." ".'~..:~~.."~ 5%~4r.?f:\~'~."~ oz. . . '.>~ ..,: '. . . ~~~f~!~g~~~~~~..::~::::~.<. I¿~~;...:~' ':F~~:.:~-; ::;;.::" :,,:,:'~~~:j:~~s;:~ -- -- -- -- ~m.£~ ~ì\f..¿t~~. r. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Magnets not used 0 ."'t.~ .~~.:.; ~ : ': ;~.~~;~1t\.::}~.~':;~~b~:~~.~~t.tl:~~ ~'~.:..:i.... .. ~~.~':fJ.'~".t~\r~~ 24 hr Recé Cont la in down BHA #2, N/D diverter stack, N/U BOP stack.RJU test 'oint, Test BOp.s, Passed. UD test 'oint, blow down mud lines and to drive. Service To Drive. Start RJU BHA #3. ~_::~~T~1=i2::3ri£!EI"~'7'~:~',' '.\'.'.~¡ "':~<~,;~'~ ':,.;", ;'".,,',,', ": ~"--'.." I~."¡~":. * 1 0000 units = 100% Gas In Air .,:",i- ;, ::,'.; '::~<::iC,~':'~,~,'.. BP Alaska Northstar NS 13 North Slope Northstar NS 13 Nabors 33E AKAM 11103 '.~ ,,~,(;:t ~'l.1fr \í:~J~F '~... ~~~.'S! Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: spef'"'1ry-sun . ._- - . . . - --. - I:J A 1 L...I...I N G 5 e A VI c:: e 5 -'-----'-'-'-----" .--.- ---. -.--- -- ----.- Mudlogger's Morning Report ',¡... ;,"'f" .: -).'.- . " , ,~-~'.,:,..... ,,':~;:-~~'~''i.;'\;>-~<¥il.1;~:~~. .. ~~~~~_'M3~~~:.'t,IÆ.(~~:,,;:f¡,:,~'a\~~~,r~;ioS~ -\;~4if.;~~'.-~1~;~ ~:,' I Current 24 hr Avg R.O.P. 13 ftfh r 167 ftfhr ( I Gas* 10 units 5 unit~ ( , Temp Out 55 Deg F ( 24 hr Max 721 ftfhr @ 20 units @ deg F @ 6 6/21/01 3575 360 Drilling Joe Polya 3431 ) Pump 1 3449 ) Pump 2 ) Pump 3 Pump Pres Pump and Flow Data 100 spm DH flow 100 spm Total flow spm AV @ rsr 1200 psi AV @ DC ,.:,:;..v . ~~\:., '~:'~~:',~~:;.,; ~ .""'~'< " -' '..:: , ~~ il. - ,,:~~:;';f~\~~~\:'.'Ì;fJ~~ . .- ~ 710 Mud Wt In Mud Wt Out 8.80 ppg Visc 49 secs API filt 6.2 ml HTHP 0.0 ml Mud Wt at Max Gas - - 8.80 ppg PV 13 cP YP 21 Ibs/100ft2 Gels 6 \ 7 Ibs/100ft2 pH 9.6 Sd -- .' ,'.,! " '~?,~ ' ., '~::!=~::J.:,::~ ::~.'L',:Z~:=L::.~t::,:.~:~~:¡~::;;¿:j;:~~.E.::'~~:.~~~~._'"~~.:~=~=,=:'.":i,::~'~:=-Z~~=::::'~£::::~~~:~ ~~~~~. ,~~.; r:':J2[::2I~~~~'::'~~. ~,~~..' ~.~:,j ~Ir.,\,fi'.: I ,. I I ~.' I I I Type: MX-CS1DT1 Bit Size: 121/4 5/20 RPM: 60 Hrs. On Bit: 6.0 Jets: ~ \ ~ \ -1!L \ -1!L \ - \ - TFA: 1.0060 Total Revs on Bit: 0 Footage for Bit Run 360 Bit No.: 2 Wt On Bit: , ,~ ." Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: to to 70 % % SO 30 0 % Current Lithology: 0 % slst ft ft ft Connection Gas and Mud Cut ft units -ppg ft units - ppg ft units ppg ft ft ft units -ppg units - ppg units ppg Drilling Breaks Drill Rate during Depth Gas during before after before after to to ~...~~~\,~.::"~." ,'.:':.:::':....,:¿~i'~'~~:.~. "., :'>~.~~i~~'f~.;;~(",..'1!r.t~ J ,,', ., '~1\r.~fii~iII;'.~~i. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Splinters. shavings I some thin wirey pieces. 5 oz. .'. ,.ti~~~f;~~~ ;.~..:~DJ;'&~'~~;: ::.~. ".:-.'~~~~li~.?!tIlf'£f[:' 15000 ppm ppm ft %LCM units -ppg units -ppg units ppg % Lithology Cgl Sst Ls Sh ---- -- -- ---- -- -- ~-~~7et~V:::c.".~J .; ~~'~1:j ~ . .Q~' .~.. : ,,; ~.~r ", ~;'~~<.:.. . .~ ,,: "'.:<::~<:::,;;~:J,>:;~~;~t-=æ~~~:f;!e:~~"i' :, .;. '* 10000 units = 100% Gas In Air Logging Engineer: Mark Lindloff / Wayne Hermanson spe""r'v-sun CfAI L.L IN G 5 e À V Ii::: e 5 -------- - .-.,.u---_.,----.-~ '----'--'-,,-.-..-, ,--_.._-.-~.._- Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: ;;'" -., . ,";l:.:.t!~jW~,~.!', :.Mæ:~!})i~"t~;~~~ . ~¡.?;,:g{;I'\';:~~'r.'~~;~,iJ¿'k~¡mt~::;:¡;^".#,:;¡<!~~~\\¡ :':;i<.;,'~,; ;',:.;;1,;~'\\.S".. Customer: BP Alaska Well: Northstar NS 13 Area: North Slope Lease: Northstar NS 13 Rig: Nabors 33E Job No.: AK AM 11103 7 6/22/01 5140 1565 Drilling Joe POlya Mudlogger's Morning Report . ~ ,,, -,:I ',: , ~ "':I .' ~;1t.."S.~'~ç:J.-;.i:...;;,:,;¡,~"~,;::¿¡~t":¡'.i:*"r~:~'.;;.;.;:¡".,,,;¡¡, . I Current 120 ftlhr 35 units 80 Deg F 4667 ) Pump 1 3449 ) Pump 2 ) Pump 3 Pump Pres Pump and Flow Data 100 spm DH flow 100 spm Total flow spm AV @ rsr 1500 psi AV @ DC 24 hr Avg 205 ftlhr ( 65 unit~ ( ( 24 hr Max 896 ftlhr @ 255 units @ 0 deg F @ R.O.P. Gas" Temp Out .' ". ~ .' .. ,'~,- ':>:oif....::;.':'~~.~-;e: .' '::'t'Q)l.:iJ;;~.:i~:.:::'.,~'t.¡I!iI'r.~'~~?'..4~,~,,~'~;,..,:.i:I""t~¡'::".:k::;'''' :'<!~',-('~'!."." I)"o\."~':' "".;' '. .'" I Mud Wt In Mud Wt Out 710 -- 9.20 ppg Visc 46 secs APlfilt ~ml HTHP ~ml MudWtatMaxGas -ppg 9.20 ppg PV 14 cP YP 20 Ibs/100ft2 Gels 7 \ 10 Ibs/100ft2 pH 9.0 Sd 0.5 % ~ I after !.. ,~r' .\".'.,'..,,:E.t~:'~:=~):~~:,::::;.:~Z-':~:=~::":'=:~,".'..,:2'~.:=:.[.:L~::~~~.~. .-~~=~~_:'1~::,~~~:S::~.:Q::::~::i:::'I,~ :~~~~3i~f~'.~~~~~~'l~ ,~:!i~~~ ~ "'i\~~I~'t.~:;:':~~r:'''~~:,'\ '. Type: MX-CS1DT1 Bit Size: 121/4 5/15 RPM: 100 Hrs. On Bit: 10.3 Jets: 16 \ 16 \ 20 \ 20 \ \ TFA: 1.0060 ------ Total Revs on Bit: 0 Footage for Bit Run 1925 I Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: 4256 ft Short Trip Gas: to 137 Mud Cut: - ppg Trip CI: ppm Mud Cut: - ppg Short Trip CI: 38000 ppm to Feet of Fill on Bottom: ft I ~ to I ' Current Lithology: CLY 20 % % 80 SO % 0 0 % Connection Gas and Mud Cut ft units -ppg ft units -ppg ft units ppg I ft ft ft units - ppg units -ppg units ppg ft ft ft I I ;i: ";¡Ì :',¡ ,¡,I: I:'~ Drilling Breaks Drill Rate during Depth Gas during before after before to to I I "'. .,\t->;-:.:.::.':..~f,.,;\..,j:,{;:.. .,... . .."'" ..~.:..~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Magnets not used ,.. 3 oz. I ~:;""~:-'"..'~",~...",,~~~.,~,~:w.~Z2:.J~~~~7'~;~~~?:~~,~~~~~~,~r;:~'~'2~. f/~.'~;' "\.'~~' %LCM units - ppg units - ppg units ppg % Lithology Cgl Sst Ls Sh ---- ---- -- -- ..:::~, t:;,/.(:<r~~J,.~{f'Ifk~::;;:¡~ ;:~j,...~./.~.t:,\i~~'~~:;,þ.i-i& "1!~~~ . ~. ~:~~~:; .:r ..:7 ~,.,~:: 24 hr Recé Cont Drillin F/3575 T/4256'. Short tri ed to shoe, Ran back in the hole to bottom, circ bottoms U I with 137 units of tri as. Cont drillin F/4256 T/5140 ;¡ ; ~ Logging Engineer: Mark Lindloff / Wayne Hermanson .- ,....,--¡. ..' . ' i,. ',~~;: :;:... ." ;., .' . . ,,::.'":.., ...: -" . .:' rl,j,.. ;~,'{.: .:~ ~,,,.... . ~~>L~~~Jfä'II . . ~.m-¡-~e.~.' ., * 10000 units = 100% Gas In Air .i.5~\:t~;¡r~i~\%~:~ill:Y~,(.. ~. r ( r ( I I I ' I I ( ,',,;\;l:~" :. :.;,.: >.::; \~}\m~i:)i¡¡,~l1.'~ Customer: Well: Area: Lease: Rig: Job No.: .;".,..,1,-" ~. ..~'''~ " " . . . j,:, . ..~; ,~¿-~,.~~<:;, :.:' :;jqi.¡¡'. BP Alaska Northstar NS 13 North Slope Northstar NS 13 Nabors 33E AK AM 11103 spe.....,.....,v- sun ÇJ-~-ç~~-' 1,,'- G ._--"~-§.,,~ ~h'~~~:§~-§ Mudlogger's Morning Report Current 81 52 85 . t ,'" .'1 ,.'~,~~*,:rJ~~1~:{~~ ',.. :Î-~¡:r~i~:t!::'::~'':'~i~~~'!~W ,;;;;¡..: ''7, Report No.: 8 Date: 6/23/01 Depth 6329 Footage Last 24 hrs: 1189 Rig Activity: Drilling Report For: Joe Polya Shows: , '~"..: ~:;~.'~~.:....:. :"',~ ,:, .1,~",;~~~;'d~~)"..',,,,~'." '"h,,:., :..,,::<>"V :~..',~~,j';.J.,.;¥.<~~\~~ .. : ;H~¡';¡'~...:"Ú~6~"4tt~:.~~~'3'<:.'~", ~'!~~~'~?:;..i'"","" '. '~+1'~' . ..:<i~! ",,~,.. 24 hr Avg 24 hr Max Pump and Flow Data ftlhr 157 ftlhr ( 613 ftlhr @ 5714 ) Pump 1 100 spm DH flow units 136 unit~ ( 1081 units @ 5908 ) Pump 2 100 spm Total flow 710 Deg F ( 85 deg F @ 6157 ) Pump 3 spm AV @ rsr Pump Pres 1750 psi A V @ DC . . ~...:i-. ~.~:',:...d~¿1',:.:~jii~~~..7;:;'.:~ ":. ~'.~"~' .I:..J;:;';~~~:--' .~¿~~~.:~~!t.:~tt.' Drill Rate during :~~' ..'\~1;..~~tr!'~'.:.~~~~~;:.if,:"~:'~"~'-~"'~' ~ ~ . R.O.P. Gas* Temp Out Mud Wt In Mud Wt Out 9.30 ppg Visc 51 secs API filt 5.6 ml HTHP 0.0 ml Mud Wt at Max Gas - ppg 9.30 ppg PV 17 cP YP 24 Ibs/100ft2 Gels 9 \ 14 Ibs/100ft2 pH 9.3 Sd 0.25 % -- ~' '~.~r;~L ':'¡1;~1Ii<'," Type: MX-CS1 DT1 Bit Size: 12 1/4 5/30 RPM: 100 Hrs. On Bit: Jets: 16 \ 16 \ 20 \ 20 \ \ TFA: 1.0060 ------ Total Revs on Bit: 0 Footage for Bit Run 3114 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm - Short Trip Depth 5212 ft Short Trip Gas: 30 Mud Cut: -ppg Short Trip CI: 39000 ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 60 % CLYST 60 % SD 20 % SLST % %LCM ft ft ft units - ppg units - ppg units ppg Connection Gas and Mud Cut ft units -ppg ft units - ppg ft units ppg ft ft ft units - ppg units -ppg units ppg Depth before Drilling Breaks after Gas during after % Lithology Cgl Sst Ls Sh before -- -- to to "" . ~- ;~~ff.~~~ ):.~tt:~t; ~~~f::::~: ":'" "' '; ", '~'. :.{: ~~:~':~ :~~~~;~ '~;:~~:f~~$it?~~!~~:~~ ---- ---- ---- 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Magnets were clean of metal 0 oz. ~ ,- ~... . , 24 hr Recé Continue to drill F/5140 T/5213, Wi er tri back T/4258, no roblems. Run back in hole to bottom and start drillin F5213 T/6329. NOTE: Fluoresence were noted in sample 5500' md to 5600' md. Gas maxed at 1081 units, d. No heavies in gas were note Logging Engineer: Mark Lindloff / Wayne Hermanson . ,-.. .''''.'..~:.;;~~~,:.'~,~'i,*\t.iiI. {~,':,,:: .'~.'.¡ .."".'~W~ ""¡ * 1 0000 units = 1 00% Gas In Air .;t~ ~i~ ~~',.tg\/i\t:i~~~i*i<fP0;-. .:,..:~~ '~-. h:~,jr~,~:,~'?~~'..~/f'~I,:::~~: "~ - ," "~":.~',~:1~~'.':i:, ~:\'~~! Customer: Well: Area: Lease: Rig: Job No.: ~. .~. BP Alaska Northstar NS 13 North Slope Northstar NS 13 Nabors 33E AKAM 11103 '~\\''ifi'::}~'~'~;:f*~~~~iÆt'*' ,! Y.:' '¡.:ß~f':'~':0;:;,,:,,\ ,,; ., :',' s:'Ú.\il:fi4j~~~D~;~~:2'~' ' Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 9 6/24/01 6655 316 Drilling Joe Polya ..i' spe""""V-5un - .- .- . - -" ". .., 0 R I L.L IN G 5 e R v I c: e 5 ------.-------.-.,-. --"~-~-- Mudlogger's Morning Report \." . . ,c,.'. '~;'.,'"..., ; 'i,",;~~~l~.:~~;t:,'i:~of,:liì;",\~;¡¡;'';'hi.~~:''''''!1t~}"",., ~¡'A\~-{\:!' \",~ ..: \;',;;..:.Z"....~f3!'bi{:";~ ;,;,,'l';¡:!!'i~~-1>N'~~:~I~., :.~~ 'ct".;\'1i1::,~,:o' . Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 143 ft/h r 143 ft/hr ( 438 ft/hr @ 5714 ) Pump 1 110 spm DH flow I ,,;to Gas" 66 units 22 unit~ ( 147 units @ 6442 ) Pump 2 110 spm Total flow 790 Temp Out 75 Deg F ( 0 deg F @ 0 ) Pump 3 spm AV @ rsr Pump Pres 1850 psi A V @ DC I I I I r I i~ )~ I I r .. :'~: :,:",~','~.';.~::i:~~~jl'.:;:)I: ..~'~' 1'" !~:\,~~,:..'t.,:",;~;:, ,', ,',,' t :;,:',,,,.:,'C,:,,:.,':';:"~:.'.I^'i;~~,. ,~"';~ Mud Wt In Mud Wt Out 9.30 ppg Visc 51 secs API filt 5.6 ml HTHP 0.0 ml Mud Wt at Max Gas - ppg 9.30 ppg PV 14 cP YP 26 Ibs/100ft2 Gels 10 \ 14 Ibs/100ft2 pH 9.0 Sd 0.5 % -- Type: DS69HFGNPUV Bit Size: 12 1/4 5/30 RPM: 100 Hrs. On Bit: Jets: 15 \ 15 \ 15 \ 15 \ 15 \ 15 TFA: 1.0350 ------ Total Revs on Bit: 0 Footage for Bit Run 3114 Trip Depth: 6442 ft Trip Gas: 147 Mud Cut: -ppg Trip CI: 34000 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 % CLYST 20 % SO 40 % SLST % %LCM ft ft ft units - ppg units - ppg units ppg Drill Rate during Connection Gas and Mud Cut ft units -ppg ft units - ppg ft units ppg ft ft ft units -ppg units -ppg units ppg Drilling Breaks after Gas during after % Lithology Cgl Sst Ls Sh Depth before to to before -- -- ---- ---- -- . ;:;~::.~'~~~'_. :' ": .~(, '::~:~." ;~..'~~~~I~~~'~¡ ',~,: \~:'~;~~~;j~~'i~~~;'~.>2:.~.~:~~~'::~~: :'~"~.:f.~)~t~~ ~ ~ . oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Magnets were clean of metal - ::;".~~~. 0 .. , ~:',::t~r~,~~~~:~'. ~~:- .~ .~ ,; ,... ~~~{~:".,.~~4-:,~,",,'~;~~':~~!~'f~::.;i).,~~~~::';~ ~~ .~:~~~$t!:~~."'f ~~~~.~~~t:~:; :~ .', A: "~:~:;,~ 24 hr Recê Drill T/6442', cir, POOH for bit tri No Problems, UD BHA. M/U BHA #4, RIH T/3215, SIi and cut .,j... Drill Line. Resume RIH ,Pum Pill I 147 Units of TG at bottoms u ,Drilled F/6442' T/6655' MD ".' , ', .C':~:,i ,;'~,'~~~~(~?~:T;~,1~\Stj'~~~!7}V;I~~, " . '~,~ . ',.,'~.~sr~TI"c.7,~:~ ~.~\~.~~.,.~.~', ':."~' ',I . .~~~~-~,'" Logging Engineer: Mark Lindloff I Wayne Hermanson * 10000 units = 100% Gas InAir ~ ~ t:::Þ . . ~ " . " ~ , . , , ' .,' . ,: .:, --:-.'>;"":'..:': ,'. ;.:~~~,;.:.;.:::¡:t+~f.~ft:;~¿.4t~~~tl~t;!fÛi .' ". . "'''''".' .. .:.:., .;...,:~~~~~:~~~t;£Új::,:~~~:;,:..-. ".;;;;~ ',:--,:'~. ~ ..."',\.;~'~.~::~~~~:.:;'i.,l 'I ~.., ~.~,. \. ~ . ". " , ,. .'r',' .':'5\D~ . \':, ':l::Ø:'i!i!ii ;~';:I)~~~~t:~~,,1ti::¡~{/:i¡¡iit~t'~:t:-J.IT~~~1»~rr.~~~\M~.-;~'a:~~r-<,1"/Ä,¡¡",!?,,,!..:~¡Iti~"f1,:¡'1t1?'~Y:;', sper--'ry-sun Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 10 6/25/01 8805 2150 Drilling Christian/Dinger J J:'~,).'-:-~' ..,..;:"~:~:. . :,,; ~...' . Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 130 fUhr 188 fUhr ( 748 fUhr @ 7133 ) Pump 1 110 spm DH flow Gas. 63 units 136 unit~ ( 665 units @ 7250 ) Pump 2 110 spm Total flow 780 Temp Out 75 Deg F ( 0 deg F @ 0 ) Pump 3 spm AV @ rsr Pump Pres 2175 psi A V @ DC I ( ( ( ( ( ( ( ',' ( ( ( BP Alaska Northstar NS 13 North Slope Northstar NS 13 Nabors 33E AK AM 11103 --..---,-.-. ,._--.-~_._.". --- --- - -..-.., -.---- t:J A I L..L..I N G 5 e A v I c: e 5 ------.------,.---------.-- - ,,--- ----- Mudlogger's Morning Report .;. .i.l, A~' ù:. :.II~~.\~~~n.:r,p,:l:,i~~ì~~.r-,~~~~..?I', ¡,:-~;,':~I',.~',."..:.." :~.~;.;;.~ ìtij~'~.~'" .. Mud Wt In Mud Wt Out 9.30 ppg Visc 51 secs 9.30 ppg PV 14 cP API filt 5.6 ml HTHP 0.0 ml Mud Wt at Max Gas - ppg YP 26 Ibs/100ft2 Gels 10 \ 14 Ibs/100ft2 pH 9.0 Sd 0.5 % -- ",j¡¡ Type: DS69HFGNPUV Bit Size: 121/4 Jets: 15 \ 15 \ 15 \ 15 \ 15 \ 15 TFA: 1.0350 ------ 5/15 RPM: 100 Hrs. On Bit: 19.0 Total Revs on Bit: 0 Footage for Bit Run 2363 Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: to to 40 % CLYST 50 % SLST 10 % SST % Current Lithology: Connection Gas and Mud Cut ft units - ppg ft units - ppg ft units ppg ft ft ft units -ppg units - ppg units ppg ft ft ft Drilling Breaks Drill Rate during Depth Gas during before after before after to to .: . ~ . . .'.' . . . ::::.~:X:'~.:' ::j~;~'~~.~~ ' 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Magnets were clean of metal 0 oz. : ::'I~~'J::.CI'~~. ~~'~~î~~;r1i~~~i;; '" :';za.~~'i.:~:I~¡&r:;.~."= .~~ ~;,:c-~~~ 24 hr ReCé Drillin ahead F/6655 T/8805. 34000 ppm ppm ft %LCM units -ppg units - ppg units ppg % Lithology Cgl Sst Ls Sh -- -- -- -- ---- :'~~;..~~':'2.~'; .~.: ':~1~'~ ~ :,,"~ :~.:" ~~~~ .;:::~:~~~~.: I y~' . * 10000 units = 100% Gas In Air Logging Engineer: Mark Lindloff / Wayne Hermanson '. ~~:.~~.~~.:. .'" . ~:~~ .~~~~,~ -:~..~ . .. :.~.. I I I, [ I I I [ I [ I [ [ I [ I I I I . '-~ ~ . ". :\: ~X~:'>':'~:-~~~¡', ''';t~F~i~lilo1;;~',~~*v.¡¡'i;'S,¡'~ . 1i)f.r~~~f¡~:~~:i~~'¡m:{:,,~::.. 'f_il"'~:(~<. ,.,,~,::;~~:t..'~~¡t¡t;, 'P .;-¡¡,~. Customer: BP Alaska Well: Northstar NS 13 Area: North Slope lease: Northstar NS 13 Rig: Nabors 33E Job No.: AK AM 11103 Report No.: Date: Depth Footage last 24 hrs: Rig Activity: Report For: Shows: 11 6/26/01 9715 910 Drilling Christian/Dinger ., ' '~'¡'f;"::>'.~"...",~, ,,~,.'. .. -'..:'~~.~ I~'-"I_. ~~,;:~~~;.;:"'~i', ;~,'¡. "~~~"~r~¡,f:~J:¡-.'-;.':.;:,\;'::' . ~ ",,~ ~~l ~ ~ gpm¡ gpm :.~~ fp m'~;:: ~\~ fpm f~1 Type: DS69HFGNPUV Bit Size: 121/4 Jets: 15 \ 15 \ 15 \ 15 \ 15 \ 15 TFA: 1.0350 ------ 10/20 RPM: 100 Hrs. On Bit: 30.0 Total Revs on Bit: 0 Footage for Bit Run 3270 Connection Gas and Mud Cut ft units -ppg ft units -ppg ft units ppg ft ft ft units -ppg units -ppg units ppg ft ft ft sperry-sun d A I L:L..I Ñ- G 5 e A V., c: e 5 --_. -~- - ~----,-_._--,- ---.- ..--. ,---- Mudlogger's Morning Report . '.Í'.,¡:,~,':\t-'Uj.,~ ~~., R.O.P. Gas" Current 130 ftIhr 1892 units 107 Deg F 8944 9663 0 Pump and Flow Data 110 spm DH flow 110 spm Total flow spm AV @ rsr 2750 psi AV @ DC I', Trip Depth: ft Trip Gas: Mud Cut: -ppg Trip CI: ppm Short Trip Depth 9400 ft Short Trip Gas: 6237 Mud Cut: ~ppg Short Trip CI: 34000 ppm Tight Spots: 7200' to 6450 to to Feet of Fill on Bottom: ft Current Lithology: 10 % CLYST 20 % SLST 70 % SH % %LCM . '. ;.;" 24 hr Avg 24 hr Max 152 ftIhr ( 576 ftIhr @ 306 unit~ ( 4358 units @ ( 0 deg F @ Temp Out ~-~..- Mud Wt In Mud Wt Out 9.80 ppg Visc 51 secs API filt 5.8 ml HTHP 13.6 ml Mud Wt at Max Gas 9.80 ppg PV 17 cP YP 22 Ibs/100ft2 Gels 12 \ 30 Ibs/100ft2 pH 8.8 780 units -ppg units -ppg units ppg % Lithology Cgl Sst Ls Sh -- -- -- .. ',;.';~~;'~~~. Drilling Breaks Drill Rate during Depth Gas during ---- -- -- before after before after -- -- .~, ~-;jt~:,¡:tl~' ;'to'. . 24 hr Recé Drilled F/8805' Md T/9400' MD, CBU, POOH T/6400' MD, Ti ht Sots F/7200' T/6450', was able to work thru w/o um s, RIH back to bottom, no roblems, CBU, With 6237 units of Wi er Tri Gas. Drilled F/9400 T/9725. with 4358 units of drill gas at 9663 MD. Currently drilling on to 10254' to to '-~' :.:~ ~~: ':, : ~. ~:.;~~}~/~\.:~ .':i';'" .. .:;.: ..,;.>~...: ,:..;:<.:.,:.:-.:{~t¡J~~~: ,. " ..., . ;.r 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Magnets were clean of metal 0 oz. . ':;;';~:j;;~51i~1~~<1;\.;¡:~,~mJ~. !, ' Logging Engineer: Mark Lindloff / Wayne Hermanson . "h._.' . ::;~:';J~:;"..'!:i~.i.+~ ',: ~,t {~itf.~~ ~t~ .. * 10000 units = 100% Gas In Air .1 ...~II' , Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: !~~i;~~;~:¡F ~' ~\i\tl\r. .~'~. ~ '~~~h~j,¥:.,~ ~L:~~~.¡,"rm:;¿~'}.\~~~,i"i::/.,:: '~~: ..~,;, ":' . Customer: Well: Area: Lease: Rig: Job No.: BP Alaska Northstar NS 13 North Slope Northstar NS 13 Nabors 33E AKAM 11103 .1'.~",..¡ " . " Mudlogger's Morning Report ~~1, sperrv-sun -. -- --- -- -, C A I LL IN G 5 e A v I c:: e 5 ---.------.- ..-.---,-.,.---.---,----- Current 0 0 107 R.O.P. Gas. Temp Out . , '_l '., ~., ..~.~~!..-.',:,,~~-!:;..;':.f.1i~~~~~~',J':"'I~ 1;t!,JI.!~ " 12 6/27/01 10104 389 Drilling Christian/Dinger . ~.~1):f'4"ì.'irIN~t"l.:"(:> 24 hr Avg 24 hr Max Pump and Flow Data ftIhr 39 ftIhr ( 653 ft/hr @ 9991 ) Pump 1 0 spm DH flow units 285 unit~ ( 3286 units @ 9689 ) Pump 2 0 spm Total flow 0 Deg F ( 0 deg F @ 0 ) Pump 3 spm AV @ rsr Pump Pres 0 psi A V @ DC . ',~fìt~,\¡'I¡:, ~,.!Iiii(*~~-:\:i:")l!".i . .;1ii.~""".!,:~~~\.,'š'..~~;'.;¡':i.i.:'\Ió;¡f"¡,,:'".¡. Mud Wt In Mud Wt Out . ~!§.'\ï1L'iit.~,i>;i:,,;,::;;' 9.80 ppg Visc 51 secs API filt 2L ml HTHP ~ ml Mud Wt at Max Gas ~ ppg 9.80 ppg PV 17 cP YP 22 Ibs/100ft2 Gels 12 \ 30 Ibs/100ft2 pH 8.8 Sd 0.1 % -- [ I Trip Depth: Short Trip Depth Tight Spots: I [ , Current Lithology: ft ft ft I [ Depth to to I I ~ .. _.::'J~~~:~':~l~/:~:1i.'~~J:j:/t~\~~:.:.: Type: DS69HFGNPUV Bit Size: 12 1/4 0.00 RPM: 0 Hrs. On Bit: 40.9 Jets: 15 \ 15 \ 15 \ 15 \ 15 \ 15 TFA: 1.0350 ------ Total Revs on Bit: 0 Footage for Bit Run 3661' ,,-~ 6250 to ft Trip Gas: ft Short Trip Gas: 6230 to Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: 80 % 10 % SLST 10 % SD % SH units - ppg units - ppg units ppg Connection Gas and Mud Cut ft units - ppg ft units - ppg ft units ppg ft ft ft Drilling Breaks before Drill Rate during after Gas during after before . ..',/: ":/;;:.;k:.;:;;~~;;.!.~, ;.< : ~;!~fl~~rF'~' ">tp~.; .. ~ .~ I 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Magnets were clean of metal oz. 0 ppm ppm ft %LCM units - ppg units - ppg units ppg % Lithology Cgl Sst Ls Sh ---- -- -- -- -- ---- ':~ ':-:~;'~p::,~;:-.~:.,~:.~::~~~~.~:;: ~:~~. .~. :'~;~-':"11'tJ#~?(,~~~i?' ",' "",,', .' ,':'':f¡~7~~~'~,:r;~~?:i;-'i:::Þ~.2~~2?7'~I=£~7~~~~,:''.' .', :I'äfi,~.....z..~i!~':;:I'" .;" . 24 hr Recé Drilled to intermediate casin oint at 10104'. Drill as eaked to 3073 units at 9782.00' MD. CBU, then urn ed d 'ob. POOH one ti ht s ot F/6250 T/6230, worked threw aka. La down BHA. . ".:<j~.~. "\\~~j::. ..~'<'~::..,.' Logging Engineer: Mark Lindloff / Wayne Hermanson . ,. . . ,. .<''''¡.'.i'_~:ff~,:;¡!:.'~.::,~~1t.~¡4,-*§~~~~!d-"t(¡[~~!1'.'''"' , .' :.~:< ".,.":;(.:..-:.;7:~f~_~~T_~Ü~~~~~Øi ' , ~.'~~.Wg~i«g~ril:;hj!Jt~i;~;~,:..'~~ ,.' y... ::. >.;.~ . '" ~,~~' ~ ~\,.'~.\.' " .'~;;, i~::~~;:", :';~:~:~. ~,' ~\; .L. .~,.~:!~~~..j~ t',:,,:&~~~~ "\.,,, ":~,'::.'~; h~\~ ~; ,::'~1~~~,,¡,:~";~!'\r~~?~~ \ ,'~¡;\ ""~J~\:~r:~~:~:ù~~;v.7.~" spe....,....,v- sun Customer: Well: Area: Lease: Rig: Job No.: ----_.-- ""'0- --u- ~-----,- --..-. '--.-,.--...-",-- I:J R I L..L..I N G 5 e R v I c: e 5 --------_.,'_._-,_..~---- Mudlogger's Morning Report ... ~.:... . , .'-.:,""." " ,:""' .~;- :".,~':1,;'!\:\i,(t\'r.'~'~.l!.1~- I Current 0 ftIhr 0 units 70 Deg F 0 0 0 24 hr Avg 0 ftIhr ( 0 unit~ ( ( . R.O.P. . Gas* Temp Out .:.?tf"C':,j", ,', "::,,¡-î"~;*,,~"~iW;.~O~"'~i~')~7~~1Ii/i!~;~:iq~" :..' Mud Wt In Mud Wt Out BP Alaska Northstar NS 13 North Slope Northstar NS 13 Nabors 33E AK AM 11103 ..~'...a~ 24 hr Max ftIhr @ units @ deg F @ œt.1¡f..~~', Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: :. ~,"~wø.' ,~ "".' ~ - 13 6/28/01 10104 0 Elogs Christian/Dinger 0 0 0 ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres Pump and Flow Data 0 spm DH flow 0 spm Total flow spm AV @ rsr psi A V @ DC . , ~ . -. . .:øJ Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: 10 % SD % 0 0 9.80 ppg Visc 47 secs API tilt 6.8 ml HTHP 13.8 ml Mud Wt at Max Gas -ppg 9.80 ppg PV 16 cP YP 15 Ibs/100ft2 Gels 7 \ 18 Ibs/100ft2 pH 7.8 Sd 0.1 % -- I ;j ~~I Bit No.: 0 '~i! Wt On Bit: ". .1IiIt~:.,,,. .. Type: RPM: 0 0 Bit Size: 0 Hrs. On Bit: 0.0 0.00 I ô, Trip Depth: Short Trip Depth Tight Spots: . to ft Trip Gas: ft Short Trip Gas: I 80 % Jets: 0 \ 0 \ 0 \ 0 \ 0 \ 15 TFA: 0.0000 ------ Total Revs on Bit: 0 Footage for Bit Run 0 to SH 10 % SLST Current Lithology: units - ppg units - ppg units ppg Connection Gas and Mud Cut ft units - ppg ft units -ppg ft units ppg ft ft ft I ft ft ft I -: :, r. f. I, t;~ ;~,,', . Depth Drill Rate during before to to 1 ..,.. ::'.....: '. . ~ïc~ .....:.~..: ~':. :':':~"..::.:.:/;;;'.'\.:'.. . ..:\{~;~?~:~~;Þ¡:5!i:..:::'i%l.këi:f;~W~ ~"'. Drilling Breaks after before I 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: No Drilling or rotating of pipe this day . 24 hr Recé Logging Engineer: Mark Lindloff / Wayne Hermanson Gas during after 0 ~::'.~;.:~;" .: :.I...:~~'~:~~. '.~~:li.>',".::i~~~!;..~:~.?:; :~.~~~i~!.~~::, ~~~.:~:l~~~i~~~~~'. ~ ~ '.~~:~.'(\1,:.~~~:..,: \:;"., ~~lW~~;';~I?t~~;~;:.f¡~~~;i~~r' ~~.:..- ::.~~~ ppm ppm ft %LCM units - ppg units - ppg units ppg % Lithology Cgl Sst Ls Sh -- -- -- -- ---- ---- I I I I I I 1 ' I I ;;," ;~ ~,~ ~~~ :Ì! I Xt~ I,~ 1 I I I I " ,~~.t'" .'\ : . C:/~','i~.t~:,~~; i :~ ':~;~'1'.. . '. .:::~,,;,,-,,:'iJ..~~ , ~. Customer: Well: Area: Lease: Rig: Job No.: BP Alaska Northstar NS 13 North Slope Northstar NS 13 Nabors 33E AKAM 11103 :,~~ð-:i-'f.:.r.i,.' ~:i~:t~.£W1J~¡¡~~i~~;i~'J:~~t;¡'¡fI;:~;:¡¡~;:t$£;~::;:: ':: ~ Report No.: 14 Date: 6/29/01 Depth 10104 Footage Last 24 hrs: 0 Rig Activity: POOH Report For: Christian Shows: ""'. « .. - gpm, 530 gpm '~.: fpm fpm . . Mud Wt In Mud Wt Out 9.90 ppg Visc 53 secs API filt 7.5 ml HTHP 0.0 ml Mud Wt at Max Gas - - 9.90 ppg PV 16 cP YP 22 Ibs/100ft2 Gels 10 \ 29 Ibs/100ft2 pH 8.4 Sd -- . Logging Engineer: Mark Lindloff / Wayne Hermanson ':- t~ .. ".Q:'F" Current 0 ftIhr 0 units 90 Deg F 24 hr Avg 24 hr Max 0 ftIhr ( 0 ftIhr @ 170 unit~ ( 4239 units @ ( 0 deg F @ 0 ) Pump 1 9030 ) Pump 2 0 ) Pump 3 Pump Pres Pump and Flow Data 74 spm DH flow 76 spm Total flow spm AV @ rsr 1380 psi AV @ DC . . ':~hØ" .. : ,". - '.... . .' ':'~'''". .' "., .~.'-,'.'''' . . = . .~ . '. . I . ',. ..:: .~., -. . - . 4245 Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: I 1 ¡-;'I No.: 5 ~.~ :~J Wt On Bit: I' ~'f $, Trip Depth: 1 Short Trip Depth Tight Spots: sper...,v-sun [J A I L...L.I N G 5 e A.V..-C: e 5 ----- Mudlogger's Morning Report . '" ~. . ",'''''''',:-:''1. . ~",,~'~:-:'~1\,,~~'\1' r', ..,. '~:~-:'~I: '," -..:.: .~, ..,.-~"','~~~.+~~~kÌ¡ . to 80 % SH 10 % SLST % Type: MXCSDT1 Bit Size: 12 1/4 Jets: 16 \ 16 \ 20 \ 20 \ 0 \ 0 TF A: 1.0060 ------ 5/10 RPM: 90 Hrs. On Bit: 0.0 Total Revs on Bit: 0 Footage for Bit Run 0 10 % R.O.P. Gas" Temp Out -. .~', '~'l.~$~~~,~:,? .,:~~~~~1~~~:S:~~~'.,~ ;~~,ìJ,:~'~~.v~.....~.~".:...'~, '/,~, ~~;~.:,r"7\'~>~~~~: , k:¡ ìf 10104 ft Trip Gas: ft Short Trip Gas: SD ft ft ft units - ppg units - ppg units ppg Connection Gas and Mud Cut ft units - ppg ft units - ppg ft units ppg ft ft ft 30000 ppm ppm ft %LCM units -ppg units -ppg units ppg after Gas during after % Lithology Cgl Sst Ls Sh -- -- -- - --,..- - - -- .'..::~:7;"~:!:~ .::;'1."~'"1~*:i~!~:\:. .'" :", '.~~"~:~~~.~ ~:".:i~~ :.~~ ~"".:' ;:::~¡:~~!~;~. ~. oz. Drilling Breaks before -- -- 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: METAL SHAVINGS TR 24 hr Reci RIG DOWN WIRELlNE, TEST BOPS. RIH AND BREAK CIRCULATION AT 3000',6000' AND 9000'. WASH DOWN TO TD. CIRCULATE HOLE TO BOTTOMS UP WITH TG GAS PEAKING AT 4245 UNITS. CaNT TO CIR HOLE CLEAN TO 1 1/2 TIMES BOTTOMS UP. POOH TO RUN INTERMEDIATE CASING. to Current Lithology: Depth Drill Rate during before to to .;":"~~":~~~\~~:. '.~~J~', a:.":~J..~..;,~~~;~JJr..~'~'::~~.l"~~"" ; * 10000 units = 100% Gas In Air . ,}~,,~';-:~~'.,.'k, ~.i,\';~~'~i'~'::~;. :,':~ ':"~', '-, '":r,l~ sper'...,v-sun ~;~W"". Customer: BP Alaska Well: Northstar NS 13 Area: North Slope Lease: Northstar NS 13 Rig: Nabors 33E Job No.: AK AM 11103 - --------.--.-. --." -.-.--..-- ..--... ..---. .-.------- [J A I L...L...I N G 5 e A v I c: e s Mudlogger's Morning Report ";' ~.~ ,,:"~ '.;- ':,~~' ~'~;~",')'''. ,~. ¡~~ . ~.'~.'. ":':~.'~:a:.:~..":"';'::".,.~.~ .~ï.~'\I"".~)r,t;s.~.ò.~~~"\t I ~ , ~, Current 0 ftlh r 0 units 90 Deg F 24 hr Avg 0 ftlhr ( 0 unit~ ( ( 0 0 0 24 hr Max ftlhr @ units @ deg F @ R.O.P. Gas. -- Temp Out . ",,::\';i..:.,¿:-~l~..,,~ ¡iM~~~itM~.\'t':~",'#",;,:~W,¡(>.;,-~.:~~~)t:J';'¿¡'~~~ Mud Wt In Mud Wt Out Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: ':;)16Li:'~: r, .' '''~J''::;~¡, 15 6/30/01 10104 0 POOH Polya/Christian .."~~. '. .... 0 0 0 ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres Pump and Flow Data 0 spm DH flow 0 spm Total flow spm AV @ rsr psi A V @ DC -- 0 9.90 ppg Visc 51 secs 9.90 ppg PV 15 cP API filt ~ ml HTHP ~ ml Mud Wt at Max Gas - ppg YP 22 Ibs/100ft2 Gels 9 \ 22 Ibs/100ft2 pH 8.1 Sd 0.01 % Type: 0.00 RPM: 0 0 Bit Size: 0 Hrs. On Bit 0.0 Jets: \ -- Total Revs on Bit \ \ \ TFA: ---- a Footage for Bit Run 0 [ [ Trip Depth: Short Trip Depth Tight Spots: to [ before ft Trip Gas: ft Short Trip Gas: to [ 80 % 10 % SLST 10 Current Lithology: SH 0 Mud Cut - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: % SO % [ units - ppg units - ppg units ppg Connection Gas and Mud Cut ft units - ppg ft units -ppg ft units ppg ft ft ft ft ft ft [ Drilling Breaks [ Depth Drill Rate during before after [ to to [ '..'. ", .:::. . .:. .~.' ,'''', '.~ .. ~...:::_~'...: :.,...,~.~:~::.: ..'::~fi:::.::... '.:.~.~~~~~i,>~~~~~~ì!:~~;:~~:~~~ , . '., . ' 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: No Circulating today. [ Gas during after ppm ppm ft %LCM units - ppg units - ppg units ppg % Lithology Cgl Sst Ls Sh -- -- oz. ---- -- -- , 24 hr Recé CONT TO POOH, LAY DOWN BHA#5, RIG UP CASING TOOLS, CURRENTL YRUNNING CASING. Logging Engineer: Mark Lindloff / Wayne Hermanson * 10000 units = 100% Gas In Air ~,:~'~:':.~:~<:~r. '.~. :~: :.\~.."~..~'~~.~~~~;~' :~ ..~ . . :. ,~~::.',~ ~~:0;~:"i:~~;1¥~f~J , ~~Yt~i.;;f~".:'.'J~~~.~".':f~*:f.m~_i~~:~'~\~~';,: ;.~r.~~~~77:~.~:~~~(~~~:~7.'.;';~':~~:P.!.,'i"~:~.:~",~.. ..". .,:".,." ""..<'~,;': ...l. .">i ..~'.{~;/(~',: ,:';'~~<~'~~}:~~~~,':\~\~~I';' I'" , ': 'ÛT';: \.~!~:, -:~...a~J~, ': ,', " ;'" ~'," ,.:Z :f~; .'~,~¡~:~,~?-t~~~~., "~, " . ,. 5per'~V-5un Customer: Well: Area: Lease: Rig: Job No.: BP Alaska Northstar NS 13 North Slope Northstar NS 13 Nabors 33E AK AM 11103 --- ,.", -,--,._--------- " ------- ,.- ---,-'---, _.-- .- ".. -'-,--_.- C A I ~L..I N G 5 e A_~ I c: e § Mudlogger's Morning Report ~,:~*',:,:~V'r - ";;';"ii:t!.;i:',;f¡j 'r~,;.i¡¡,... '. ,";,,~\':.''i.l.r~;t;¡;'';;¥....'¡;',~ "{,'--~\'V,.;L.. .' Current 0 ft/hr 0 units 70 Deg F 24 hr Avg 24 hr Max 0 ft/hr ( 0 ft/hr @ 0 unit~ ( 1115 units @ ( 0 deg F @ , R.O.P. , Gas. : Temp Out . i., ,-'~':ø.:ø:(\<L\Íi1;;~~"fi,~:,\í',i&\\\'i!<"'''iIIia_~~~'' Mud Wt In Mud Wt Out .~'{. ,~,,~ I Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 16 7/1/01 10104 0 PICK UP BHA Polya/Christian 0 0 0 ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres Pump and Flow Data 0 spm DH flow 0 spm Total flow spm AV @ rsr psi A V @ DC gpm --L gpm fpm fpm 0 9.90 ppg Visc 53 secs API filt ~ ml HTHP -1.i.1. ml Mud Wt at Max Gas - ppg 9.90 ppg PV 18 cP YP 16 Ibs/100ft2 Gels 11 \ 27 Ibs/100ft2 pH 8.0 Sd 0.01 % -- I I I I I I I I I Drilling Breaks Type: DS70FNPV Bit Size: 81/2 0.00 RPM: 0 Hrs. On Bit: 0.0 Jets: 15 \ 15 \ 15 \ 13 \ 13 \ 13 TFA: 0.9070 ------ Total Revs on Bit: 0 Footage for Bit Run 0 Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to 80 % 10 % SLST Current Lithology: 10 SH Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: % SD % ft ft ft units - ppg units - ppg units ppg Connection Gas and Mud Cut ft units - ppg ft units - ppg ft units ppg ft ft ft 24 hr Reci CONTINUE TO RUN IN WITH 9 5/8" CASING, WASH TO BOTTOM. CIRC AND CONDITION MUD. GAS MAXED 1115 UNITS. PUMP CMT AS PER WELL PLAN, INSTALL 9 5/8" PACK OFF, TEST TO 5000 PSI PUMPED 198 BBlS OF 9.8 DOWN 13 3/8" x 9 5/8" ANNULUS. PREPARING TO PU BHA #4 AND RIH. Depth Drill Rate during before before after to to . .~:~~':~.mff.~f~~l~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: SMALL SLIVERS , Logging Engineer: Doug Wilson/Mark Lindloff Gas during after ppm ppm ft %LCM units - ppg units -ppg units ppg % Lithology Cgl Sst Ls Sh ---- ---- -- -- oz. * 10000 units = 100% Gas In Air ". ,:.t;;~:~~~~::;':'~~:'jr~':~;€~,:?~~~: ~;~"}~~'~':." . .~ '\.~~:~?~~::i~~;~¡¡~~~~:i:":":§~?~. ",'~~." !:~'~~,-"'~" ,.?",~,'~?IF~:~~~,~r:~ '~~'~7~:r*~::'~"~::~.,:~..~~~Wf~~:'''~~':f~~~~~?~.~~??:;""7'~:,;\~,::'~;:,':.X,:",~':":'::, '~"'~":,- ",:,;';: ~::,',~'~':::: ~ ,:~." :':':!~~;;~,";(:"': ~,~..;j~m,..,;:.~~r.~,::~~7~~~7!~~.',:''¡';::,,;' ~~"~',~~~~~ ~S~wrSlffi.z~~717:~~:~::,:~~~~I~::'=~~~~~'bt(,~ ,. 24 hr Max Pump and Flow Data 514 ftlhr @ 10491 ) Pump 1 77 spm DH flow gpm - 264 units @ 10198 ) Pump 2 77 spm Total flow 550 gpm 0 deg F @ 0 ) Pump 3 spm AV @ rsr fpm Pump Pres 2650 psi A V @ DC fpm I I r r I : ;~:~\~ ~\~';!,~:'~, "?<;, ~'~/~~~ "r¡~;::~~I>.t~,,,:'~ ", :.' ~~ ;}&;'\'t~~~~:::~~~~llt;;~~~'!!~r~r~' ~~,X¡¡"'~~ t~~t\~ ' . ,,) C '. sper'r'V-5Un : .._,._----- .- ----" '--'---- -._u -- CAI L-LI N G S e A v Ices ---.'.--,--. _n_..- Mudlogger's Morning Report .. ...,~"'~~~"'"~::,,,¡~..1':I~'fIì!,W~~,~>'" .': Current 24 hr Avg R.O.P. 0 ftlhr 1 18 ftlhr Gas. 16 units 72 unit~ Temp Out 70 Deg F .. ., ", .. ,¿:P~:~,,,>/, " : ~.:~ :~:!~~~.~'t.:~ :~"~1\~gÚ~:'~i .~. ;~.t! ','l,~~'~,l~~;~~~~~~~~!:i'::{Î~~~¡;~'~~"":.~l~r .; ~ )\.~. Mud Wt In 11.30 ppg Visc 53 .;: Mud Wt Out 11.30 ppg PV 18 cP .'.1 - ~!":'~~~~~~':~~2YS~'~~;:C:~ Bit No.: 4 Type: DS70FNPV Wt On Bit: 10/12 RPM: 50 Hr ustomer: Well: Area: Lease: Rig: Job No.: BP Alaska Northstar NS 13 North Slope Northstar NS 13 Nabors 33E AK AM 11103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 17 7/2/01 10,411 307 Drilling Polya/Christian secs ~~~~~;~~~~,:~.,:, API filt ~ ml HTHP -1i.! ml Mud Wt at Max Gas - ppg YP 16 Ibs/100ft2 Gels 11 \ 27 Ibs/100ft2 pH 8.0 Sd 0.01 % -- I I I I I I I [ r I I I . I I ~:~.' ::'::.,~..~:_'::.:~.:: .~, --. '::..~ .~.::::':.,:~.,' . ~..; .~:.~{:,::':'.',=::~' .'. :c':~ ::.', ::: .:'..:._,'.:~:;:: .'.~':" ...: ...: --~.:~..~~":':~=.~~::,:':':'::'~;',:~:;~~;::'~,~:,;2;~2.2,:[~1:. :.: OJ Jets: 15 \ 15 \ 15 \ 13 \ 13 \ 13 TFA: 0.9070 ------ Total Revs on Bit: 0 Footage for Bit Run 307 ~~;'~!:i~'.~~ ::' ~,;..~.'~1'1'::~:,'"~~','~,~~.=~'=~~';,':'.~' '~!'-~,",,~:,.~~,~1.:~~,~:~ ,: .,.~.:~~~~~~,~~:._:"~-',. ~~'.:,~~,:."~~~'~.:~:~~'.',.,,:'..,, ~" ,.. ,~. '~-'."""," ':.,. .., -. ' .,,,' .."', '. ,,' ',,< '".. ", " '.: '" '".. :" , ". .' ."' ,..' . ~,..~ "., ~ ,. ' ,'., "',,.', :,' ., ,,~. '.. ,"" '~,,' ,.' .., '"' -'.""'..' ""..' . '.." ,. ,,' ...,,: ,,',~~.,..~, :,." .'~~".~~', ", -' ",,'-.. .:::.:.: ,'.. :~"':'~"'~":":':"~'R:~"" :~~;;:,~:':.;~.... ,'. 1 Bit Size: 8 1/2 s. On Bit: 4.1 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: 90 % SH 10 % SLST % % %LCM Connection Gas and Mud Cut ft units - ppg ft units - ppg ft units ppg ft ft ft ft ft ft units - ppg units -ppg units ppg Drilling Breaks Gas during Depth Drill Rate during after before before after to to units -ppg units -ppg units ppg % Lithology Cgl Sst Ls Sh ---- -- -- -- -- -- 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: SMALL SLIVERS ,.:..,:\ti;:'M1k'f~,~~':i\'1rMi:~W~'JIJ_;h~~'. . 24 hr Recé M/U BHA #5, RIH, CIRC & CONDITION MUD, TEST CSG 3000 PSI FOR 30 MIN, PASSED. CLEAN CMT F/9814 T/9997, TEST CSG 3000 PSI FOR TEN MIN, DRILL OUT FLOAT EQUIPMENT F/999? T/100?9 WASH & REAM F/10079 T/10104. CIRC & COND MUD FOR L.O.T.. PERFORM L.O.T., 15 PPG. CIRC TO RAISE MUD WEIGHT TO 11.3 PPG. CONT DRLG F/1 0124 T/10295, REPAIR MUD PUMPS, CONT DRLG F/1 0295 1 oz. Logging Engineer: Doug Wilson/Mark Lindloff ~~1Z:::J-:~:p~.~.I'~:....:~: ~.~ .:' .~..~~.:.,'. '~::':~ . .' i~;~:~:(.;7;,: ~"~:..:' :~~::;,~r~~~~~~,~l ,,:,r.; -;."':};~~¡'~~\"'i~i~l~~r~~~'0~;1t'~~~Jji~~~ . .~!¿:i(~7£~~"-:~~i::'~~':,~'~.:::':':'i.:',S§2E~L~3]ß1~~:r}~~',~~:~~~:]:~-;;:,~:.~;T;L'~~"'~"''''''~ ~~'t\ 0 RILL I N G 5 e A V I c: e 5 Customer: Well: Area: Lease: Rig: Job No.: BP Alaska Northstar NS 13 North Slope Northstar NS 13 Nabors 33E AK AM 11103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 18 7/3/01 11490 1,079 Drilling Polya/Christian " ., spef""'1...,v-sun --.-- -..-----,.-.----..--.- ----_._~~. ..;> Mudlogger's Morning Report ,~.~~"'t':!i#:"~,,!{~~~~~--~ ~ ':, ~~C;:=2~=~~:.':,=,:=~,~~'.~:"=~~~z:.:=:~::~--=~~:.~":2'~=~~~2~~:~~,:='-'-'7=;r~ Current 24 hr Avg 24 hr Max Pump and Flow Data . R.O.P. 115 ftIhr 100 ftIhr ( 328 ftIhr @ 10442 ) Pump 1 77 spm DH flow gpm - , Gas* 142 units 102 unit~ ( 212 units @ 10198 ) Pump 2 77 spm Total flow 550 gpm Temp Out 70 Deg F ( 0 deg F @ 0 ) Pump 3 spm AV @ rsr fpm Pump Pres 2900 psi A V @ DC fpm I I I , I I I I I I I 24 hour accumulation of Steel Filings from Possum Belly Magnets: I Desen':::t filling,s: SMALL SLIVERS ~ 24 hr Recé Cont drillin F/10411' MD T/11490" MD, circ bottoms u I Tri back to the bottom, circulate bottoms u . I ': Logging Engineer: DouS Wilson/Mark Lindloff I Mud Wt In 11.30 ppg Vise 53 secs API tilt ~ ml HTHP --....:!.!.i ml Mud Wt at Max Gas - ppg Mud Wt Out 11.30 ppg PV 18 cP YP 16 Ibs/100ft2 Gels 11 \ 27 Ibs/100ft2 pH 8.0 Sd 0.01 % -- ft ft ft units - ppg units - ppg units - ppg Connection Gas and Mud Cut ft units -ppg ft units - ppg ft units -ppg ft ft ft units -ppg units -ppg units - ppg .~~. ~ Type: DS70FNPV Bit Size: 8 1/2 10.00 RPM: 80 Hrs. On Bit: 15.1 Jets: 15 \ 15 \ 15 \ 13 \ 13 \ 13 TFA: 0.9070 ------ Total Revs on Bit: 0 Footage for Bit Run 1386 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: 90 % SH 10 % SLST % % %LCM Drilling Breaks Depth before Drill Rate during after before Gas during after % Lithology Cgl Sst Ls Sh to to -- -- -- -- -- -- -- -- oz. ~ , ~' . - - ,.....-... - - - ,--- ,--- ---. ~ Component Cumulative Sensor Length Length Measure ~ ~ ~~ 930.02 Distance ToBit (ft) Drill Pipe Drill Pipe (S) - . 5.0000 in OD ~ 1.00 ~.; 929.02 HWDP HWDP;: 5.0000 In OD , 788.10 Drilling Jars Dailey Jar 7.7500 in OD MONEL DC Drill Collar 8.1300 in OD Monel Stabilizer Stabilizer 8.0000 in OD MONEL DC Drill Collar 7.9400 in OD 140.92 31~1 109.41 30.85 78~6 5.63 72.93 30.74 42.19 MONEL DC Drill Collar ~ 8.0600 in OD 30.94 ~ 11.25 Monel Stabilizer Stabilizer 8.0000 in OD 5.62 1 ,t! .,~ I Bit Sub WI FLOAT Sub [I 5.63 7.8800 in OD 2.93 xoxo [I 2.70 9.5000 in OD 1.35 HTC. GTX-CPSSG1 Bit iii 1.35 16.0000 in OD 1.35 Drill Pipe Drill Pipe (G) 5.0000 in OD HWDP HWDP 5.0000 in OD Drilling Jars HYD Jar 7.7500 in OD Monel collar Drill Collar 8.1250 in OD Monel Stabilizer Stabilizer 8.0000 in OD MONEL DC Drill Collar 7.9400 in OD MONEL DC Drill Collar 8.0600 in OD Monel Stabilizer Stabilizer 8.0000 in OD Orienting Sub Sub 8.0000 in OD ----8--~-ANA-MWD~MWD-~~ 8.4400 in OD Mônel Stabilizer Stabilizer 8.0000 in OD MONEL LC Drill Collar 8.0600 in OD Monel LC Drill Collar 8.0000 in OD 9-5/8" STD MTR 1.83* PDM 9.6300 in OD XOXO 9.5000 in OD MXC-1 Bit 16.0000 in OD Component Cumulative Length Length (ft) (ft) 4009.33 ~ I ~ ~ ~ ~ ~ ~ [J .~ ~ [I ~ [I [J - 1.35 3,000.00 788.10 31.52 30.85 5.63 30.74 30.94 5.62 1.66 29.04 5.62 10.45 9.72 26.74 1.35 Sensor Measure Point Distance To Bit (ft) 1009.33 221.23 189.71 158.86 153.23 122.49 91.55 85.93 84.27 55.23 49.61 39.16 29.44 2.70 1.35 - - - Drill Pipe Drill Pipe (5) 5.0000 in OD HWDP HWDP 5.0000 in OD Drilling Jars Dailey Jar 7.7500 in 00 MONEL DC Drill Collar 8.1300 in OD Monel Stabilizer Stabilizer 8.0000 in OD MONEL DC Drill Collar 8.0600 in 00 MONEL DC Drill Collar 7.9400 in OD Monel Stabilizer Stabilizer 8.0000 in 00 ----.-- 8 7/16" ANA MWD MWD 8.4400 in OD 8 3/16" ANA COR MWD 8.3125 in OD Monel Stabilizer Stabilizer 8.0000 in 00 MONEL LC Drill Collar 8.0000 in 00 9-5/8" XP PDM 1.5 PDM 9.6300 in OD MX-CS10T1 Bit 12.2500 in OD fI [I ~ fI fI fI fI fI II 27.61 [I. 22.80 fI fI fI fill 1.00 Component Cumulative Length Length (ft) (ft) 1022.37 Sensor Measure Point Distance To Bit (ft) 1.00 1021.37 788.89 232.48 31.51 200.97 30.85 170.12 5.44 164.68 30.94 133.74 30.74 103.00 5.55 91.45 - --- -- 89.84 47.04 5.49 41.55 9.72 31.83 30.83 1.00 - - --. - ...-- -- Drill Pipe Drill Pipe (S) 5.0000 in OD DART VALVE DART VALVE 6.3120 in OD HWDP HWDP 5.0000 in OD 6.75" ANA ADN MWD 6.8800 in OD HWDP HWDP 5.0000 in OD Drilling Jars Dailey Jar 7.7500 in OD MONEL DC Drill Collar 8.1300 in OD Monel Stabilizer Stabilizer 8.0000 in OD MONEL DC Drill Collar 8.0600 in OD MONEL DC Drill Collar 7.9400 in OD -. ~ . Monel Stabilizer Stabilizer 8.0000 in OD 8 7/16õõ ANA MWD MWD 8.4400 in OD 8 3116" ANA CDR MWD 8.3125 in OD Monel Stabilizer Stabilizer 8.0000 in OD MONELLC Drill Collar 8.0000 in OD 9-518" XP PDM 1.5 PDM 9.6300 in OD DS69HFGNPUV Bit 12.2500 in OD Component Cumulative Length Length (ft) (ft) 6442.80 ~ 5,394.77 ~ I 728.21 II II ~ 31.51 II 30.85 II 5.~ II 30.94 . .. ..[1... 30.74 II 5.~ II 27.63 II 22.82 II 5.49 II 9.72 II 30.83 iiiiiI 1.00 3.37 23.25 60.68 Sensor Measure Point Distance To Bit (ft) 1048.03 1044.66 316.45 293.20 232.52 201.01 170.16 164.72 133.78 103.04 87.49 69.86 47.04 41.55 31.83 1.00 Drill Pipe Drill Pipe (S) 5.0000 in OD DART VALVE DART VALVE 6.3130 in OD HWDP HWDP 5.0000 in OD Drilling Jars HYD Jar 6.5000 in OD HWDP HWDP 5.0000 in OD XOXO 6.6300 in OD ANA NM FLEX Flex 6.7500 in OD ANA NM FLEX Flex 6.7500 in OD 6.813" ANA MWD MWD 6.7500 in OD 6.75" ANA CDR MWD 6.8130 in OD Monel Stabilizer Stabilizer 6.7500 in OD 6.75 XP PDM 6.7500 in OD Hycalog DS70FNPV Bit 8.5000 in OD Component Cumulative Length Length (ft) (ft) 10104.00 Sensor Measure Point Distance To Bit (ft) ~ 9,105.76 ~ 3.37 I 702.15 ~ I lJ 1.67 ~ 31.01 ~ 31.02 11- 24.30-105.45 ~ ~ 22.27 ~ 5.69 ~ 25.26 iiiit 1.00 998.24 994.87 292.72 32.60 260.12 90.97 169.15 167.48 136.47 81.15 26.93 54.22 31.95 26.26 1.00 I [.Ischlumbergeri- - _.. I . ~o.~-~ - AOO06427 CUS:tom...!1 . ~P ADW Wel~ ... -~S13 - - ~---+-_. Field NOI1hstar .. R¡¡- - Nabors 33E ~_:.~~E~131307 001- levad : -ë;M;J LockwoOd I Dinger: OM Run - N/A ! POM Sen I POM Sin Mud Type BHT P lt8m !script Bil ¡l/:1 GTX-C PSG1 1 A=1.0 -ove I ~SeaH20 Spud 2 E ITSU 3 tco of MO~eL S A8 4 M DNEL C I 5 M þNEL C 6 MO~EL 5 A8 7 I M þNEL C 8 [os Ion rYD JA~ 9 26 J . HW P 5" 10 DP 5 to Su rface 11 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 I I I Rell/Ga I MudW16.8 I Mud VI.! 80 I V8IIdoT I HTC Ana Ana Ana Ana Ana Ana Ana Dalley NAD NAD 0 0 0 0 0 0 0 0 I I RIS S"g8.5 0.0 -u ...;. -. -.---. -+-.------- I n__o_~_t~!~16-JutH)1 : TI~'f:01 ! .--¡;;PtIJ/'1199 I TVO 1~199 L-. -- Orlg H';Þ.2 L Slide HnO.O ---;u:: ::~:~ POM Je 0.00 B...r¡n~þ Rubbe Þ Sand "0 Solids ,,~ 00 SIN 500CM 16 3x20,1 x12 GLDD-179 10 3 GLDO-120 8 3 1100-011-58 8 3 831-D21DC 8 3 831-0020C 8 3 800-010-S8 8 3 831-0190C 8 3 1417.1119 8 3 28 HWDP 5 3 DP 5 4 0 : 0 8HA havfor.". Clean out 20" qonductor. Gyro su ey conductor. xpect co~ductorito be straight. : 8HA Actu¥' Se/lfvtor. ~s expected. : ...onductor~ev¡at.d 13 deg ~ Az. 1411. i i LiomlÐ81Itf I RyfOll fot Trip: I pOOd run. Gyro I1Jr good. POOH to P~ motor. MWD. : I i i H_-..._.L.~~O.~"8-Jun-01 i - _._':I_~e SIZ~ 16 i____-._.~Tlme O~:OO : !. :00 ',' i --.- Hole s--e"urtace ¡- Depth O~~ Bha Typabean out I -.-_u - _T:v° O~30 I ._.._~ BR7T10 ¡ Drlg F~ 1 I Avg ROP 55 Slide F Þ I Slide ROP Rot Fþ1 Rot ROP 55 Rotate :o Slide " Inellr 0.00 Az I~~.OO Bit>SII) ~IA Ine/Ou .30 Az Ou 144.1 () TIF Cor N/A AlIg Db 0.7 Max D/~ 1.3 Plan OLs .0 RP1I40 GPAI~50 I SPP On. SO Rot rc; 2 WOB~ I SPP Off. SO StIIb 00 '.' 'F.N. Connect/OIl 0 7 5/8 Reg P 7 5/8 Reg B 8 5/8 Reg P 8 5/8 Reg 8 6 5/8 H90 8 6 5/8 H-90 P 6 518 H-90 8 8 5/8 H-90 P 8 5/8 H-90 8 6 5/8 H-90 P 6 5/8 H-90 8 6 518 H-90 P 6 5/8 H-90 8 II 5/8 H-90 P 6 5/8 H.90 8 8 5/8 H-90 P 4 1/2 IF 8 o41/21FP 41/2 IF 8 o41121FP 41/2 IF 8 0 0 0 0 0 0 0 0 0 0 0 0 0 --- - ~--- :BHA~ . r.--.- ..-- ~ .- ID 0.00 0.00 0.00 16 2.40 0.00 0.00 16 2.40 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0 0 0 0 0.00 0.00 0 I Sit 0.111 ". TOOj I IADC~ 115 Moto I Foolagd 31 J~ I Hr~ 0.2 Bit'1I I k Rev~ 0 k i ¡ Grad6IGreen : I I ColTJlTHtnNViIl re-run : ' 1 I . ~ ! -- -.-- Length CUm t.ength 1.35 1.35 1.35 2.70 2.93 5.63 5.62 11.25 30.94 42.19 30.74 72.9~ 5.63 78.5E 30.85 109.41 31.51 140.9~ 788.89 929.81 0.00 929.81 0.00 0.0( 0.00 O.OC 0.00 O.DC 0.00 O.OC 0.00 O.DC 0.00 C.DC 0.00 C.OC 0.00 C.DC 0.00 C.DC HIS. In Hrs. Out 2.0 0.2 0.0 0.2 2.0 - . -llSchlumbergerf I ¡ Job. Custom.~ ~0006427 . . ;SP AOW NS13 Wall .- ¡:"'d ~onhstar ._~ _. -.-. Rig AFE'¡ OO'S , - --...--¡--- Co. Man , Nabors 33E ~3 1307 evad / Rinke ockwood / Dinger' OM Run ~ POM Sent PO", SiZ8 Mþ/4 StlglIJ~.5 Rev/Ga«J.221 Mud WI~.O Mud V/~~5 Vendor 1 962.1056 10 SeaH20 Spud Mud Ty". SHT Ii If8m !script Bit 1lI1 GTX.C PSG1 1 A-1.0 -OVE HTC 2 95/8 tdPO~1.83 3 -Float Ana Ana M þNEL C 4 Ana MþNEL C 5 Ana MO EL5 AB 6 Ana MWD 7 Ana Or! nting ub 8 ule 5h MO ELS AB Ana 9 Ana MNELC 10 Ana M INEL C 11 MO EL 5 AB Ana I 12 MNELC 13 ~slon r YO JAR Ana Ana 14 26 J ~. HWI P S- 15 DP 5 to 5urface 16 Dailey NAD NAD 0 0 0 0 0 0 0 0 0 -~. ~__L__.___... -._- --.L. --_. ! ; : .. Date /~18.Jun-01 : . . '.'-- --n';';~:oo I ---------o;Pth IrbO j_h. -.- ?:V° 1~30 I Drlg Hrs(21. , Slid. Hrs .1 Rot Hrs17.0 Pump Hrs 8.2 PO", Je Blk Searing \/Iud RubbetF!M1000 Sand "'1 Solids " OD SIN SOOCM GLOD-179 962-1056 81 0-003-L C 8-10-001-LC 800-007-5B 27531 GLOD-ð78 800.01 1.5a 831-021DC 831-002DC 800-01 0.58 831-0190C 1417-1119 26 HWDP DP .- 16 3x20,1x12 10 10 8 8 8 8 8 8 8 8 8 8 8 5 5 I 0 i 0 BHA IMvier. prill to 13 3/8* þg pnt. Expect 6/1PO slide, hold rotate. Plan to drilj to CSQ pnt. : I ElHA ACrufl ~vlor. ~s expected. IJha gave 6.8/100 D 5 slide. held rotals. i ast 200' ~ run slower ROP than other N5 wells. bit ~m & some ¡nterm tant bit balling. I ComnNllltf I R..;on for Trip: þood run. POOH f r 13 3/8* csg. pnt. i BHA stabsiall very ballfld up. GTX-1 bit much more ~m than MXC-1 bi s on other NS wellS. ' Should rur1 MXC. bits on future wellSL Bit to: QR-68.33'. D&I-70.3<\' 0 H_.__- - ID 3 Tool 3 3 3 Tool 3 3 3 3 3 3 3 3 4 I !BHA# r-..m... .-... I . -... -L-_~a_te..911t18-Jun.01 l...-.- -- . _...L_!!~.LIt12:00 I I Depth OuC215 1_____. -r .-'".-.---- TVO OuC194 _.-.---- -_._---- Drlg Ft2985 Slide FC84 r-- Rot Ft2621 Ro~te "i88 Inc/ll 1 .30 ! Incl OU1~ 9.36 I Avg OLl~.5 I RPAI~O : Rot T'~ K SDb 00 F.N. Az It 144.10 Az OU1281 .54 Max O/~ .8 GPAI 75 WOB 20 Connection 0.00 0 7 5/8 Reg P 7 5/8 Reg B 6 5/8 Reg P 6 5/8 Reg B 6 518 H-90 B 6 518 H-90 P 6 5/8 H.90 B 6 5/8 H-90 P 6 5/8 H.90 B 6 518 H.90 P 6 518 H-90 B 6 518 H90 P 6 5/8 H90 B 6 5/8 H-90 P e 5/8 H-90 B 6 5/8 H-90 P 8 5/8 H.90 B 8 5/8 H-90 P 6 SI8 H-90 B 8 5/8 H.90 P 6 5/8 H.90 B e 5/8 H-90 P 6 5/8 H.90 B 6 5/8 H-90 P 6 5/8 H.90 a 6 5/8 H-90 P 4 112 IF a 4 1/2 IF P 4 112 IF B 4 112 IF P 4 1/2 IF B 0 0 0 0 0 0 0 0 0.00 16 17.78 0.00 0.00 16 2.39 0.00 0.00 18 2.40 0.00 0.00 16 2.40 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Blto.tJJ IADCIA 115 i 2, ¡ I._._.._--~- ... ---T --.-..-.-- ¡ . . .H~/. SiZ~ 16 i Hol. slIC,"urface ! ---Sha Ty~teerable Hrs 8R~3.0 Avg ROf 41 : -- Slide ROf 89 Rot ROf 54 SIIr»" 2 BIf>SIf) 0.32 TIF Con 88.3 Plan OLl .5 SPP On 050 SPP Ott. 300 LengtIJ CUm LenøtJI ¡ 1.35 1.3~ 1.35 2.7C 26.74 29.4-1 9.72 39.16 10.45 49.61 5.62 55.2:3 29.04 84.2~ 1.66 85.9~ 5.62 91.5~ 30.94 122.4~ 30.74 153.2' 5.63 158.8E 30.85 189.71 31.51 221.2;'¡ 788.89 1010.11 0.00 1010.11 0.00 o.oc 0.00 o.oc 0.00 o.oc Footag~ 2985 Hr.J. 211 k R&v9. 250 ~ Grade(3-3.WT.A.E- /16.RG-TD CommenA1uch more' ear than withIMXC.' '. . Too Motol Jarsi Bit .~ , 0.00 HIS..1n ." 0.0 0.2 0.2 O.OC .Hrs.Out.'. 36.2 21.3 21.3 36.2 I i ,L]Schlumberger¡- .-.-.-.+---..-.--.---. ...j-..- n.___. -- -.-- +---- _.~e~~n~_nn___-t--~--i-. I --- --~. .4- . .--.-1-.'. _. .u_--_._- I JOI~l \40006427 I I .---.- _. .__~~-'~1-Jun-<J1 I ...._!- Da~ OuQ4-Jun-01 ¡ 1 Hole Siz~ 12 u I .-- --i~:~~ Hole Sec.nlermediale Cust~lI1e_~ --- - ~P AOW ! r- TIme 1/11 :30 Wet~ NS13 Depth 1/1 3215 : SM T~teeraÞle Fi;;;r.-.- ~onhslar ¡ TVD//1 3194 TVD Ou86025 I : Hrs SRI 179.0 .. :~I~ --"-.-~aÞors 33E I DrlfI Hrs 35.9 . _. DrlfI F~3228 ! - AVfI ROP~O -- _AFEl. !831307 Slide Hrs8.2 SlIdeF 436 \ Slide ROP170 -- DD's el/ad / Rinke Rot Hrs 29.7 RotF 2792 : Rot ROP~4 -.-- Co.Me/1 Þolya / Dinger Pump Hrs 59.0 Rotate "86 I Slide" 4 I DM Run. RIS /4 PDM Je ~Ik 'nel', 19.36 AzM ~81.~ I SIt>SV) ~3.50 PDMSe" il62-1126 Stafle~.O S.arin,. ~Ud Inel Ou 0.56 AzOIII ~84.36 ¡ TIF Con ~ 19.4 PDM Slz~ 10 R.v/Ga .221 Rubb. RM1000 AVfI D~ .8 I Max Dls~.6 ! Plan DI.s~.5 Mud TYPI <.CI-polymer Mud WI ~.3 Sand "P RPr. 100 GPAI 1700 SPP On ~450 SHT f 2 ' Mud Vis 1 Solids ,,~ Rot TC 000 WOB~5 SPP em ~650 /tIm scripl. V.",¡g, SIN '00 .".'. II) St8ÞOD ': F.N. ConnKfiOll Length CumLength. Bit #2 MX-C 10n 0 1 A=1.0 I HTC S35JP 12 2x16.2x20 0.00 6 5/8 Reg P 1.00 1.0C ~ 518 XP PC Y 1.5 6 518 Reg B 2 "Float ! Ana 962-1126 10 Tool 12 22.83 6 518 H-90 B 30.83 31.8~ M )NEl C i 6 518 H-90 P 3 Ana 810-003-lC 8 3 0.00 6 5/8 H-90 6 9.72 41.5!: MO ~El S AB 6 518 H-90 P 4 Ana 600-017-SB 8 3 12 2.40 8 5/8 H-90 B 5.49 47.0~ C[ R (Pili D) 8 518 H90 P 5 Ana (8039) 8 Tool 15.13 6 518 FH 6 22.82 69.8E MWD 8518FHP 6 Ana (27531) 8 Tool 0.00 8 518 H90 6 27.61 97.47 MO ~ElS A6 6 518 H-90 P 7 tco R Ana 800-002-S6 8 3 12 2.40 6 5/8 H-90 6 5.55 103.0~ M NEL C 6 5/8 H-90 P 8 Ana 831-0020C 8 3 0.00 8 518 H.90 B 30.74 133.7E M NEl C 8 5/8 H.90 P 9 Ana 831-021DC 8 3 0.00 6 5/8 H-90 6 30.94 164.7C MO ~ELS A6 6 5/8 H.90 P 10 Ana 800-013-S6 8 3 12 2.45 8 518 H.90 6 5.44 170.1.04 M NEl C 8 5/8 H.90 P 11 roslon Ana 831-019DC 8 3 0.00 8 5/8 H.90 B 30.85 200.~ HDJA~ 6 5/6 H.90 P 12 Dailey 1417.1119 8 3 0.00 4 112 IF B 31.51 232.5C 28J .HWI P 5" 41121FP 13 NAD 28 HWDP 5 3 0.00 4 1/2 IF B 788.89 1021.35 OP to Su -flee 4 112 IF P 14 NAD DP 5 4 0.00 4 1/2 IF B 0.00 1021.35 0 0 0 0 0.00 0 0.00 O.OC 0 0 0 0 0.00 0 0.00 a.oc 0 0 0 0 0.00 0 0.00 a.oc 0 0 0 0 0.00 0 0.00 a.oc 0 0 0 ! 0 0.00 0 0.00 a.DC 0 i 0 0 0 0.00 0 I 0.00 a.oc 9HA &pt mdB 18vfor. " pnll out OV collar. no at. shoe. Oril bit dull to top Coil/ill . I . Bit Data I T- HI$. In HIS. Out,: : I I IADC~ 117 Mol'ol 0.0 59.0 9HA Aetufl BM YIor. " ~ad a Slighl dr~pping lendancy in olary mode {BR= -0. 1100} Footag~ 3228 J arsi 21.3 57.2 Nalked let! 0.5/100 most 01 the run. i ! H~ 35.9 Bit'., 0,0 35.9 C:OII'IIII8ntf / RøFOII frK Trip: pOOH lor slow RO ; P/U PDC Þit and APN LWD 1001. k Revs¡ 511 k i 59.0 ::;ood run.: ! I I G,ade!1-3-WT-A-E-)/16-RG-PR . ~ t 10: ResP53.19 GR=64.19. PWD=54.94. 0&1=83.s,o ! ! COfllll'l6/1. I I I I I I I I . - 1.-. -_~. SChIUmb. eroerl-u- ! I I I Job aj 140008427 ~usro~~----- ~:1A:W .. .. !/e/~ 1-- ~Or1hstar f- . -- Rig r'labors 33E AFE. !631307 -.._- DO':! Levad I Bosse .C~..w;;; - LockwoOd I Dinger OM Run ~ POM Se" POM S/zl Mud Typo 8HT f Item . SCript Bit3 D 89HF NPUV I I Hycalog I I I :3 962 1128 10 I\CI-Polymer 140F RlS3/4 Stag&S~.O RevlGa p.221 Mud W1~.9 MudV/.s~7 Venc:IM A=1.0 95/8 PPO~1.15 2 -Float M þNEL C Ana 3 MoNEL S AB 4 Ana Ana I CC R (PV '0) 5 Ana MWD 6 Ana MO El S AB I 7 Ana M NEl C 8 Ana M NEl C I 9 Ana MO ElS AB 10 M NEL C 11 'Oslon ~ 110 JA~ Ana Ana I 12 2 JI . HWt P 5" 13 Dailey NAD I AON 14 earS 2-4 J . HWI P 5" 15 NAD Ana I Oar Valve Sub 16 OP! 10 SL rfac8 17 NAD BPX 0 0 0 0 0 0 0 ! ID rl ~HA ~-- --+-_.L.~.. -_._---~._-- u ---- , ! , ' I I ! Dahl OuC27-Jun-01 I Hole S/z'¡ , 2 F~-~fD~~:;:: i '::::£;~;::." :-==f OrlgF~661 .1: ; AvgROPÐO SJ/de F..-08 SlIdfI ROp(z1 Rot F~253 ~ Rot ROA149 -- Rotate ""9 ; SlldfI ~ 1 Incllr 30,56 Az In 84,36 : 8It>S~3.46 Inc/Ou .72 Az O J 8-4,06 I T/F Con¡14.2 Avg DI.! 1 ,0 I Max DI:st2.-4 Plan DLst2.0 RPN 100 GPAI 80 SPP On;!2400 Rot TC 18 WOB 0 SPP 011':2900 StlIbOD F.N. COlInection... L8IIf fh CIImLengIh, 0 6 5/8 Reg P 6 5/8 Reg B 6 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 B I =. ._-_!!_~~ 1'f!4-Jun-,,, _~+:30 Depth 1~«3 I. TV~r Drlg H 0.9 . Slide H 19.0 Rot Hr:3~1.9 Pump Hr:3~6.3 PDM Je ~Ik 8earln,~Ud Rubbe ~M1OQD Sand ,.~r Solids ,,~ OD 12 10 8 8 8 8 8 8 8 8 8 8 5 7 5 6 5 0 i 0 'JHA -... .-- ~-trlor. "~old angle ane slight walk left rota Ing. 611 00 OlS slidi,g. Ian to drU tangeill. drop 2/10010 0 d~.. drill to 9 5/. csg pnt. 'JHA Ac:tu~B8hfw'lor.prop 0.5 to 0.91100' and walk 0.5/1~0' right while rotatin'. -4/100' 0 5 wIIil!! sliding. Bit very dificult to slide. =omment I R~ ItIr TtIp:. pOOH for TO. Goeb run. it drop raja too great and bit very di~cull to slide. i ßit to: Res¡'53,191 GR=6-4.19. PWD=5-4,9-4. 0&lz834.!1.Neut=309.7.0ensF'306.5 I -- .-.- -f---+._------- --~-- SIN 201239 9621126 810-003-lC 800-017-SB (8039) MDC 169 800-002-SB 831-002DC 831.021 DC 800-013-SB 831-019DC 1-417-1119 2 HWDP ADW 227 2-4 HWDP GM7996. OP 3 1/16x4 1/2 I I i 6x15 1.0C 0.00 1.00 Tool 31.8:3 22.83 30.83 12 3 41.55 0.00 9.72 3 6 5/8 H-BO P 2.40 «5 5/8 H-BO B 8 5/8 H90 P 15.13 65/8 FH B 65/8FHP 6 5/8 H90 B 6 5/8 H.90 P 2.40 6518 H.90 B 6 5/8 H-90 P 0.00 8 5/8 H-90 B 6 5/8 H-90 P 0.00 8 5/8 H-90 B 8 5/8 H-90 P 2.45 8 5/8 H-90 B 8 5/8 H-90 P 0.00 6 5/8 H-90 B e 5/8 H-90 P 4112 IF B 4 1/2 IF P 4 1/2 IF B 41/2 IF P -41/2IFB -41/2IF P -4 1/2 IF B 4112 IF P 41/21FB -41/2IFP -41/2 IF B 0 0 0 0 0 0.00 0 Bit DaW ....." Tool HI3. In lADe * M-421 Mofol 59.0 Foo/ag~ 3661 J~ 57.2 HrsI 40.9 Bit'Z 0.0 k Rev~ 55-4 k J Grad~-2-CT-A-X-liBU- TO I Commenf)rop rate tool greal. Dìtfic~1t to slide. 56.3 12 5.49 47.04 Tool 22.82 69.86 Tool 27.63 97.49 1.51 3 12 5.55 103.04 3 30.74 133.7S 3 30.94 164.7:2 3 5.44 170.16 12 3 , 30.85 201.01 3 0.00 31.51 232.5:2 3 0.00 60.68 293.2C 10.30 24.30 317.5C Tool 8 3 728.21 1045.71 0.00 0.00 3.37 1049.08 4 0.00 0.00 1049.0S 0.00 0.00 a.oc 0.00 0.00 a.oc 0.00 a.oc Hf$. Out , 15.3 98.1 40.9 I I : ~.I Schlumberger -------- .-__.t---_n__._._th_--. ------L- ._mn_lßH~ 14-------+--.L.~---- ~. ----- I ' i I I . I . . J~bn1 .-- j40006427 -- ._---_l!!..~ It 29-Jun-<J1 1 Date °U43°-Jun-<J1 ¡ Hole S/z, 12 ~:ø.t~~!'1--. ,BP ADW nme/t 3:00 -_.~~_¡n-Ti;;;;ë) 0:01 i Hole See nlennediate Well N513 I Deptlllt 0104 -.1 Depth Ou: 0104 BM Typ. ::Iean out ---+- --~i.. ~onl1Slar TYDll 9371 TVD Ou: 9371 Hrs BR 1.0 Rig Nabo~ 33E i Drlg Ht:! 0.0 Drlg F 0 Avv ROf AFd ~31307 ; SlIdt Ht:! 0.0 Slide F 0 i SlIdt ROf _. DD'J' [Tunnell I Bosse Rot Ht:! 0.0 Rot F 0 i Rot ROf Co. Me~ Cllrisllan I Dinger I Pump Ht:! .0 Rotate:H 100 Slide :H DM Run. \'/8 ; R/S PDM J" 0.00 Inell, .72 Az/n 284.06 BIPSV) /a PDM SII" ! ; StagllJl .0 Bllllrln~ 0 Inel Ou .72 AzOu1 284.06 ' TIF Cor /8 I PDM S/z. Rev/GII Rubbll 0 AvgDI.! .0 Max DI Ö.O I Pllln DI.! .0 Mud Typt CI-polymer Mud~ .9 Sand:H race RPN 0 GPN 270 , SPP On. 425 BHT f 140 F Mud VI.! 7 Solids" Rot TC 11 WOI:O I Spp Off. 425 Item scrlPti V/HIdM SIN 00 10 St:8bOD F.N. Connection Lèngfh . CUm Lengt/t . BII#2r MX-C 1DT1 I 0 1 A"'1.0 HTC (535JP) 12 2x16,2x20 0.00 6 5/8 Reg P 1.00 1.OC IT5U 6 5/8 Reg 8 2 "Floal Ana GLDD-120 8 3 0.00 6 5/8 H90 8 2.93 3.9:: MO ~EL 5 A8 6 5/8 H-90 P 3 Ana 800-017-58 8 3 12 2.40 6 5/8 H-90 8 5.49 9.4:: M NEL C 6 5/8 H-90 P 4 Ana 831-o02DC 8 3 0.00 6 5/8 H-90 8 30.74 40.1e M NEL C 8 5/8 H-90 P 5 Ana 831-0210C 8 3 0.00 8 5/8 H-90 8 30.94 71.1C M NEL C 8 5/8 H-90 P 6 ros Ion Ana 831-o19DC 8 3 0.00 8 5/8 H-90 8 30.85 1 01.9~ ~YOJA~ 8 5/8 H-90 P 7 Dailey 1417.1119 8 3 0.00 4 1/2 IF 8 31.5:1 133.4E Oa~ Valve Sub 41/21FP 8 BPX GM7998 6 3 1I16x4 1/2 0.00 4 1/2 IF B 3.37 136.8:: 28 J . HIM P 5" 4 1/2 IF P 9 NAD 28 HWDP 5 3 0.00 41/2 IF B 788.89 925.7:;: OP~ 10 S~ face 4 1/2 IF P 10 NAD OP 5 4 0.00 4 1/2 IF B 0.00 925.7:;: 0 0 0 0 0.00 0 0.00 O.OC 0 0 0 0 0.00 0 0.00 O.OC 0 0 0 0 0.00 0 0.00 D.OC 0 0 0 0 0.00 0 0.00 D.OC 0 0 0 0 0.00 0 0.00 O.OC 0 0 0 0 0.00 0 0.00 O.OC 0 0 0 0 0.00 0 0.00 O.OC 0 0 0 0 0.00 0 0.00 O.OC 0 0 0 0 0.00 0 0.00 O.OC 0 I 0 O ! 0 0.00 0 0.00 O.OC 9HA vIor. ~o drilling. cle¡ n oullo 10104'. BltlMtll "::"", TCJOj 'Hø.1n HIS. Out . : ¡ IADC. 117 MotOl 3.0 9HAAc: ! I FootagE 0 Jars! 98.1 98.1 ! I i Hrs 0.0 Bit'2\ 35.9 35.9 t r'omm."tf I Røfon foI Trip: I pOOH 10 run casint i kR!lv~ Ok i 3.0 : I ! ! ! Gnld~1-3-WT.A-E-)/16-RG-PR ! I I : i i I CDmmen~it was prey ~usly run in BI-iA;M ¡ I I I I I I I I I ( ì .L I Schlumberger! --~-----~-_.__1-_- BHA #. 6 --.. ,-, I I Job II 140008427 ! I Oate/, 2-Ju1-01 I Oate 0uC).4-Ju1-01 Hole Slzt 9 ~~~._. BP ADW I Tlma/, .u Tlma O~:OO :30 Hole SK ntermedlate ,~~~L- . ~S13 : Oapth h 011U Oapth 01411490 Bha T)'pt SteeraÞle F"/~ Nort/'lstar TVOI, 371 TVD Ou: h0752 i Hrs BR 50,S _. ~. 'Nabors 33E I Ortg HI! 5.1 Ortg F ~388 Avg ROf 92 f--- AFE 831307 I Slide HI! .0 S/lda F II Slide ROf 0 00'3 unnell Rot HI! 5.1 RotF h388 Rot ROf 92 Co. Mar Christian 1 Polya Pump HI! 0.5 RDØt8 ~O I SUde " 0 OM Run 4 R/S /8 POM Ja ~Ik Incll~ .72 Az Ir 84.06 BIt>SV) 7.93 POM San! 87S-1231 St8ga3 5.0 Baartns fYud Incl OUJ .59 Az Ou: 24.153 TIF Con 21.0 POM S/zt 8 314 Rav/Ga 0.275 Rubba ~M100D Avg O~ .5 Max 0~b.7 P"n D~ 0.0 Mud Typ' KCI-polymer Mud W 1.3 Sand ,,~ RPN, 0 GPII sSO SPP On. 8S0 BHT I Mud V~ 3 Solids" 13 Rot TC 19 WOf13 SPP Off. 100 Item ac~ VandM SIN ,'.;.i>:"",,- aD, ".,,:~:. "ID , St8bOD FJI. ConnecfIOn ',' . L8IIfIIb i' ,CUm/Mtgth Blt~ DS70 NPV 0 1 A-.9 Hycalog 200347 9 3x15, 3x13 0.00 4112 Reg P 1.00 1.0C I 3/4 X 4112RegB 2 .Float Ana 87S-1231 6 3/4 Tool 8 0.00 4 1/2XH B 25.26 26.2E NM TABIL ZER 41/2XHP 3 0 87S-018SB 7 3 0.00 4 1/2 XH B 5.69 31.9~ C R(PV D) 4112 XH P 4 0 7077 7 Tool 15.13 5 112 FH B 22.27 54.2 MWO S 112 FH P 5 Ana MOC-Y8S7 7 Tool 0.00 4 1/2 IF B 26.93 81.1! ADN 4 1/2 IF P 6 earS Ana AOW 227 7 Tool 8 10.30 4112 IF B 24.30 105.4! ~ MFLE o4112XHP 7 0 87S.31-o21FC 6 3I4x 5 3 2.50 o4112XHB 31.02 136.4 ~ M FLE 4 112 XH P 8 0 875-31-o18FC 6 3I4x 5 3 2.50 4 112 XH B 31.01 167.4f -OVE o4112XH P 9 TOllon Ana GLDOO41,::: 7 3 0.00 4 1/2 IF B 1.67 169.1~ 3 Jt HWI: ~ S. 4 1/2 IF P 10 NAD 3HWO~' I" 5 3 0.00 4 112 IF B 91.02 260.17 ~YDJA~ ',' I ,:: 4 112 IF P 11 Dailey 1.1~t573, ",," 7 3 1.69 o41121FB 32.60 292.77 23 J . HWI P S. 4 1/2 IF P 12 NAD 23HWDP 5 3 0.00 41/2 IF B 697.87 990.64 Dan Valve Sub 4 1/2 IF P 13 BPX GM7888 6 3 1/16x4 1/2 0.00 4 1/2 IF B 3.37 994.01 DP ~ to S~ ace 4 112 IF P 14 NAD DP 5 4 0.00 4 1/2 IF B 0.00 994.01 0 0 0 0 0.00 0 0.00 O.OC 0 0 0 0 0.00 0 0.00 O.OC 0 0 0 0 0.00 0 0.00 O.OC 0 0 0 0 0.00 0 0.00 0.0( 0 0 0 0 0.00 0 0.00 0.0( 0 0 0 0 0.00 0 0.00 O.OC ~HA vIor. ,." Prill tangent 7' casing point. Drop ivllile rotating ahead Bit DatIl ' ' :,:, TOQ . Hn:... ': Hn. 0c1t " IADCj MOI~ 0.0 30.5 IsHA AcfU I1BeII vlor. " ~verag8 drop ( f 0.3 degrees per 1 0 Footag~ 1386 Jar.. 33.4 <18.5 HfI1 1S.1 BU... 0.0 1S.1 ¡"';ommut IReI Jon foI' Trip: ~eached 8 112 ho~ TO. Will suspend Wi I for season k RøvS 210 k 30.5 GnldeO-O.CT -N-X- ER-TD ~itto: Resf37.85 GR-48.8S. PWO- ~.4. D&I"'67.93 Neut"97.4. Denl' þ4.S5 CommenJ:;ood run. I I ( I I ( I I ( ( ( ( - - - - ~ - - ~ ~ ~ - - - - - ........"":I!.... WELL NAME: OPERA TOR: CONTRACTOR: NS-13 BP ADW LOCA nON: North Star Nabors 33E AREA: STATE: North Slope Alaska Bit ISH" Bit Bit Bit Nozzles TFA Depth Hours Feet Avg. W.O.S R.P.M. I Pump Flow T B G Res Pull REMARKS Run # Make Type Size Out R.O.P. (1dbs) Pres. (gpm) 10 D L B G 0 R 1 1 Hughes GTX-CPSG1 16.00 1x12,3x20 1.031 230 0.20 31 155.0 5 40 350 550 Clean out 20" conductor 2 2 Hughes GTX-CPSG1 16.00 1x12,3x20 1.031 3215 21.10 2985 141.5 20 60 1300 675 3 3 WT A E 1/16 RG TO Re-run f/ previous 3 3 Hughes MX-CS10T1 12.25 2x16,2x20 1.006 6443 35.90 3228 89.9 25 100 1650 700 1 3 WT A E 3/16 RG PR Pull due to slow ROP 4 4 Hycalog OS69HFGNPUV 12.25 6x15 1.035 10104 40.90 3661 89.5 20 100 2900 780 2 2 CT A X I BU TO TO intermediate In Miluveach 6 6 Hycalog OS70FNPV 8.50 3x15,3x13 0.907 11490 16.00 1386 86.6 10 80 2900 550 TO at Top Sag River - ~ - --- - ~ ~ - Customer: BP ALASKA Casing Program 20 inch at 201 ft sperry-sun Well: NORTH STAR NS13 13 3/8" inch at 3197 ft Area: BEAUFORT SEA~ ALASKA 9 5/8" inch at 10083 ft DRilliNG SERVICES Lease: NORTHSTAR inch at ft Rig: NABORS DRILLING RIG 33E inch at ft Mud Company: BAROID DRILLING FLUIDS inch at ft Waterbase Mud Record Job No.: AK-AM 11103 Depth MW Vis PV YP Gets FItr HTHP Cake Sol Oil Water Sd CEe pH Pm I Pf Mf ChIorkIes Calcium Comments Date ft 1b/gaJ see LBl100 i0S/1OM mll30 mtedeoF 32's % % % % mgeIIIg ppm ppm 06/17/01 1105 9.2 65 21 34 13120 5.0 1 5.5 0.0 94.0 2.5 5.0 9.3 0.00 .05/.35 9000 600 06118101 3165 9.0 65 14 36 13118 8.0 1 4.4 0.2 95.0 1 6.0 8.7 G.GO .1/.3 7000 540 06/19101 3216 9.0 63 16 40 21/24 8.0 1 4.5 0.0 95.0 .5 6.0 8.2 0.00 0/.25 8000 520 06/20101 3216 9.0 50 13 27 14116 9.0 1 4.1 0.0 95.0 .25 6.5 8.6 0.00 .1/1.3 15000 560 06121101 3216 9.0 50 13 57 14116 9.0 1 4.1 0.0 95.0 .2 5.0 8.6 0.00 .1/1.3 15000 560 06/22/01 3326 8.8 49 13 21 6n 6.0 1 1.1 0.0 96.5 .1 0.0 9.6 0.40 .2511.8 41000 520 06123101 4931 9.2 46 14 20 7/10 6.0 1 6.0 1.0 94.0 .5 0.5 9.0 0.15 .15/1.7 38000 480 06/24101 6157 9.3 51 .17 24 9/14 6.0 1 4.3 1.5 92.0 .25 5.0 9.3 0.45 .0311.9 36000 400 06/25101 6517 9.3 51 14 26 10/14 6.0 1 4.6 1.5 92.0 .5 6.5 9.0 0.25 .15/1.7 34000 400 06/26/01 8558 9.5 47 13 21 8/18 6.0 1 5.4 1.5 91.0 .25 8.0 8.7 0.15 .15/1.6 38000 440 06127101 9618 9.8 51 17 22 12/30 6.0 14.0 1 8.1 2.0 88.0 .01 10.0 8.8 0.10 .1/1.7 36000 400 06/28101 10104 9.8 51 12 14 7/19 6.0 14.0 1 8.2 2.0 88.0 .01 10.0 8.9 0.00 .1/1.8 34000 360 06129101 10104 9.9 47 16 15 7/18 7.0 14.0 1 8.2 2.0 88.0 .01 10.0 7.8 0.00 0/1.8 34000 360 06130101 10104 9.9 53 16 22 10/29 8.0 0.0 1 8.4 2.0 88.0 .01 10.0 8.4 0.00 0/1.4 30000 600 07102101 10104 9.9 53 18 16 11/27 8.0 14.0 1 8.3 2.0 88.0 .01 11.0 8.0 0.00 0/2.4 29000 360 07103101 10399 11.3 43 17 21 5/21 5.0 12.0 1 12.7 1.8 84.0 .01 7.5 9.5 0.00 .212.2 29000 420 - ANADRIll SCHlUMBERGER survey report client... ................: BP Exploration (Alaska) Inc. Field...... ..............: Northstar We 11 . . . . . . . . . . . . . . . . . . . . .: Ns13 API number..... ..........: 50-029-20317-00 Engineer... ..............: Rathert Rig: . . . . . . . . . . . . . . . . . . . . .: Nabo rs 33 E State: . . . . . . . . . . . . . . . . . . .: Alaska ----- survey calculation methods------------- Method for positions. ....: Minimum curvature Method for DlS....... ....: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Drill Floor Depth reference..........: Driller's pipe Tally Gl above permanent.......: 15.67 ft KB above permanent.......: TOp Drive DF above permanent.......: 56.19 ft ----- vertical section origin---------------- latitude (+N/S-).. ... ....: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- platform reference point--------------- latitude (+N/S-).........: -999.25 ft Departure C+E/W-)........: -999.25 ft Azimuth from rotary table to target: 283.23 degrees 3-Jul-2001 14:40:46 page 1 of 6 spud date................: 16-Jun-01 last survey date.........: 03-Jul-01 Total accepted surveys...: 128 MD. of first survey.......: 0.00 ft MD of last survey........: 11490.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2000 Magnetic date............: 14-Jun-2001 Magnetic field strength..: 1149.81 HCNT Magnetic dec (+E/W-).....: 26.76 degrees Magnetic dip.............: 80.91 degrees ----- MWD survey Reference Refe rence G..............: Refe rence H..............: Reference Dip............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: criteria --------- 1002.69 mGa1 1149.81 HCNT 80.91 degrees C+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- corrections --------------------------- Ma~netic dec (+E/W-).....: 26.76 degrees Gr,d convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.76 degrees (Total az corr = magnetic dec - grid conv) Sag applied (V/N)........: NO degree: 0.00 - - - - ~ ,..-- - [(c)2001 Anadr;ll IDEAL ID6_1C_08]O ANADRILL SCHLUMBERGER survey Report 3-Jul-2001 14:40:46 page 2 of 6 --- -------- ------ ------ ------ ====--== ------ ---------------- --------------- ----- ----- ------ -------- ------ ------ ------ --- ---------------- ------------- ------ Seq Measured Incl Az;muth Course TVD vertical Displ D; spl Total At DLS srv, Tool # depth angle angle length depth section +N/S- +E/W- d;spl Az;m (de~/ too qual (ft) ~ (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100) type type --- -------- ------ ------- ------ ------- ---- ---------------- --------------- ---- ----- ------ -------- ------ ------- ------ ------ -------- ---------- -------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 50.00 0.40 125.40 50.00 50.00 -0.16 -0.10 0.14 0.17 125.40 0.80 GYR 3 100.00 0.70 143.40 50.00 100.00 -0.56 -0.45 0.47 0.65 133.79 0.69 GYR 4 150.00 1.20 145.60 50.00 149.99 -1.18 -1.12 0.94 1.47 139.97 1.00 GYR 5 180.00 1.30 144.10 30.00 179.98 -1.67 -1.66 1.32 2.12 141.47 0.35 GYR 6 270.00 0.40 145.80 90.00 269.97 -2.67 -2.75 2.10 3.46 142.64 1.00 GYR 7 364.90 0.17 79.49 94.90 364.87 -3.04 -2.99 2.42 3.85 141.04 0.39 GYR 8 456.00 0.19 54.83 91.10 455.97 -3.27 -2.88 2.68 3.93 137.11 0.09 GYR 9 547.00 0.06 351.08 91.00 546.97 -3.35 -2.75 2.79 3.92 134. 54 0.19 GYR 10 638.00 0.05 43.86 91.00 637.97 -3.35 -2.67 2.81 3.88 133.53 0.05 GYR 11 729.00 0.02 11.16 91. 00 728.97 -3.37 -2.63 2.84 3.87 132.75 0.04 GYR 12 820.10 0.05 340.04 91.10 820.07 -3.35 -2.58 2.83 3.83 132.27 0.04 GYR 13 911.10 0.07 307.20 91.00 911.07 -3.28 -2.51 2.78 3.74 132.06 0.04 GYR 14 1006.30 0.08 289.63 95.20 1006.27 -3.16 -2.45 2.67 3.62 132.54 0.03 GYR 15 1027.52 0.28 320.95 21.22 1027.49 -3.10 -2.40 2.62 3.56 132.51 1.02 MWD 6-ax;s 16 1124.75 0.46 351.51 97.23 1124.72 -2.77 -1.83 2.41 3.03 127.20 0.27 MWD 6-ax;s 17 1218.46 0.52 10.27 93.71 1218.42 -2.61 -1.04 2.43 2.65 113.17 0.18 MWD 6-ax;s 18 1316.02 0.37 12.01 97.56 1315.98 -2.58 -0.30 2.58 2.60 96.59 0.15 MWD 6-ax;s 19 1411.10 0.49 23.36 95.08 1411.06 -2.64 0.38 2.80 2.83 82.36 0.15 MWD 6-ax;s 20 1506.56 0.32 7.92 95.46 1506.52 -2.69 1.01 3.00 3.17 71.33 0.21 MWD 6-ax;s 21 1601.85 0.32 346.05 95.29 1601.81 -2.54 1.54 2.97 3.35 62.68 0.13 MWD 6-ax;s 22 1696.43 0.46 4.18 94.58 1696.38 -2.36 2.17 2.94 3.65 53.54 0.20 MWD 6-ax;s 23 1791.50 0.57 344.88 95.07 1791.45 -2.08 3.01 2.84 4.14 43.38 0.21 MWD 6-ax;s 24 1885.78 0.49 352.48 94.28 1885.72 -1.71 3.86 2.67 4.69 34.64 0.11 MWD 6-ax;s 25 1982.05 0.42 348.78 96.27 1981.99 -1.42 4.62 2.55 5.27 28.88 0.08 MWD 6-ax;s 26 2075.91 0.53 19.97 93.86 2075.85 -1.33 5.36 2.63 5.97 26.10 0.29 MWD 6-axis 27 2171.96 0.29 43.28 96.05 2171.90 -1.50 5.96 2.94 6.64 26.31 0.30 MWD 6-ax;s 28 2267.80 0.29 27.52 95.84 2267.74 -1.69 6.35 3.22 7.12 26.92 0.08 MWD 6-ax;s 29 2362.90 1.60 281.69 95.10 2362.82 -0.42 6.83 2.03 7.13 16.59 1.79 MWD 6-ax;s 30 2458.09 3.21 282.08 95.19 2457.93 3.58 7.66 -1.87 7.88 346.25 1.69 MWD 6-ax;s - - - - - - [(e)2001 Anadrill IDEAL ID6_1'-08]0 ANADRJLL SCHlUMBERGER Survey Report 3-Jul-2001 14:40:46 page 3 of 6 --- -------- ------ ------- ------ ------ -------- ---------------- --------------- ----- ----- ------ -------- ------ ------ ----- ---- ------ ---------- --------------- ------ Seq Measured Jnel Azimuth Course TVD vertical Displ Displ Total At DLS srv, Tool # depth angle angle length depth section +N/S- +E/W- di sp 1 Azim (de~/ too qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100) type type --- -------- ------ ------- ------ ------ ====== --====---===== --------------- ----- ----- ------ -------- ----- ------- ----- ------ --------------- ------ 31 2553.84 5.54 287.53 95.75 2553.39 10.87 9.61 -8.90 13.10 317.19 2.47 MWD 6-ax;s 32 2649.80 7.94 285.48 95.96 2648.68 22.11 12.77 -19.71 23.49 302.95 2.51 MWD 6-ax;s 33 2744.21 10.46 281.76 94.41 2741.87 37.20 16. 26 -34.39 38.04 295.31 2.74 MWD 6-axis 34 2838.85 13.10 282.17 94.64 2834.51 56.51 20.27 -53.28 57.01 290.83 2.79 MWD 6-ax;s 35 2933.95 15.23 282.16 95.10 2926.71 79.78 25.18 -76.03 80.09 288.32 2.24 MWD 6-axis 36 3029.62 17.36 283.50 95.67 3018.53 106.62 31.16 -102.20 106.84 286.96 2.26 MWD 6-axis 37 3124.94 19.10 280.65 95.32 3109.07 136.42 37.36 -131.36 136.56 285.88 2.05 MWD 6-ax;s 38 3141.73 19.36 281.54 16.79 3124.92 141.95 38.42 -136.78 142.08 285.69 2.33 M\ND 6-ax;s 39 3218.16 19.87 281.59 76.43 3196.92 167.59 43.57 -161.92 167.68 285.06 0.67 MS - 40 3313.04 21.15 281.64 94.88 3285.78 200.82 50.26 -194.48 200.87 284.49 1.35 MWD 6-axis 41 3408.41 22.22 279.60 95.37 3374.40 236.02 56.74 -229.11 236.03 283.91 1.37 MWD 6-axis 42 3503.50 24.14 279.40 95.09 3461.81 273.37 62.92 -266.03 273.37 283.31 2.02 MWD 6-axis 43 3598.71 27.51 280.23 95.21 3547.50 314.76 70.00 -306.89 314.77 282.85 3.56 MWD 6-ax;s 44 3693.83 28.26 280.94 95.12 3631.57 359.20 78.18 -350.62 359.23 282.57 0.86 MWD 6-ax;s 45 3789.74 28.71 283.41 95.91 3715.88 404.93 87.83 -395.32 404.96 282.53 1.31 MWD 6-ax;s 46 3883.58 30.08 283.03 93.84 3797.63 450.98 98.36 -440.16 451.01 282.60 1.47 MWD 6-ax;s 47 3979.40 30.27 284.00 95.82 3880.47 499.15 109.62 -486.98 499.17 282.69 0.55 MWD 6-axis 48 4075.35 29.87 283.31 95.95 . 3963. 51 547.22 120.97 -533.70 547.24 282.77 0.55 MWD 6-axis 49 4169.68 29.37 281.33 94.33 4045.51 593.83 130.92 -579.24 593.85 282.74 1.16 MWO 6-ax;s 50 4264.76 29.07 280.42 95.08 4128.49 640.20 139.68 -624.82 640.24 282.60 0.56 MWD 6-ax;s 51 4360.21 28.90 281.55 95.45 4211.99 686.42 148.49 -670.23 686.48 282.49 0.60 MWD 6-ax;s 52 4454.99 29.65 280.14 94.78 4294.66 732.72 157.20 -715.74 732.80 282.39 1.07 MWD 6-axis 53 4550.17 29.32 283.15 95.18 4377.52 779.54 166.65 -761.61 779.63 282.34 1.59 MWD 6-axis 54 4645.02 28.81 282.71 94.85 4460.42 825.62 176.96 -806.52 825 . 71 282.38 0.58 MWD 6-ax;s 55 4740.12 28.98 284.20 95.10 4543.69 871.57 187.66 -851.21 871.65 282.43 0.78 MWD 6-ax;s 56 4836.66 29.14 286.39 96.54 4628.08 918.42 200.03 -896.43 918.48 282.58 1.11 MWD 6-axis 57 4931.66 28.52 285.77 95.00 4711.30 964.17 212. 72 -940.45 964.21 282.75 0.72 MWD 6-axis 58 5026.46 28.95 287.44 94.80 4794.43 1009.67 225.74 -984.12 1009.68 282.92 0.96 MWD 6-axis 59 5121.79 29.40 286.67 95.33 4877.66 1056.03 239.37 -1028.55 1056.04 283.10 0.61 MWD 6-axis 60 5216.06 30.15 287.04 94.27 4959.49 1102.75 252.95 -1073.35 1102.75 283.26 0.82 MWD 6-axis [(c)2001 Anadr;ll IDEAL ID6_1C-08]O 4 of 6 ANADRIll SCHLUMBERGER survey Report 3-Jul-2001 14:40:46 page --- -------- ------ ------- ------ ------- ==--~=- ------------- --------------- ----- ----- ------ -------- ----- ------- ----- ------- ----------- ------------- ----- Seq Measured Incl Az;muth Course TVD verti ca 1 Displ Di sp 1 Total At DLS srv, Tool # depth angle angle length depth section +N/S- +E/W- d;spl Az;m (def/ too qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100) type type --- -------- ------ ======= ------ ======= ======== ================ =====:::======== ----- ----- ------ -------- ------ ------ ------ 61 5311.34 30.47 287.44 95.28 5041.74 1150.72 267.20 -1119.28 1150.73 283.43 0.40 MWD 6-ax;s 62 5406.83 29.94 286.78 95.49 5124.27 1198.65 281.33 -1165.19 1198.67 283.57 0.65 MWD 6-ax;s 63 5501.26 29.55 285.14 94.43 5206.26 1245.44 294.22 -1210.23 1245.48 283.66 0.96 MWD 6-ax;s 64 5597.29 29.04 286.02 96.03 5290.01 1292.39 306.84 -1255.49 1292.44 283.73 0.70 MWD 6-ax;s 65 5692.77 28.58 285.56 95.48 5373.67 1338.36 319.36 -1299.76 1338.42 283.80 0.53 MWD 6-ax;s 66 5788.22 29.37 287.32 95.45 5457.17 1384.52 332.45 -1344.11 1384.61 283.89 1.22 MWD 6-ax;s 67 5882.64 29.57 289.30 94.42 5539.38 1430.78 347.04 -1388.20 1430.92 284.04 1.05 MWD 6-ax;s 68 5978.19 28.91 287.66 95.55 5622.75 1477.25 361.84 -1432.46 1477.45 284.18 1.09 MWD 6-ax;s 69 6073.78 29.71 286.78 95.59 5706.11 1523.93 375.69 -1477.16 1524.18 284.27 0.95 MWD 6-ax;s 70 6167.71 29.83 287.09 93.93 5787.64 1570.47 389.28 -1521.77 1570.77 284.35 0.21 MWD 6-ax;s 71 6262.67 30.39 285.56 94.96 5869.79 1618.04 402.66 -1567.49 1618.38 284.41 1.00 MWD 6-ax;s 72 6354.23 30.56 284.36 91. 56 5948.70 1664.45 414.65 -1612.35 1664.81 284.42 0.69 MWD 6-ax;s 73 6382.86 30.44 284.54 28.63 5973.37 1678.98 418.27 -1626.42 1679.34 284.42 0.53 MWD 6-axis 74 6479.04 29.91 284.37 96.18 6056.51 1727.31 430.34 -1673.23 1727.69 284.42 0.56 MWD 6-axis 75 6572.72 29.50 284.39 93.68 6137.88 1773.72 441.87 -1718.20 1774.11 284.42 0.44 MWD 6-axis 76 6666.00 28.99 284.63 93.28 6219.27 1819.28 453.29 -1762.32 1819.68 284.42 0.56 MWD 6-ax;s 77 6761.07 29.35 283.74 95.07 6302.29 1865.61 464.64 -1807.24 1866.01 284.42 0.59 MWD 6-axis 78 6858.55 29.50 283.37 97.48 6387.19 1913.50 475.86 -1853.80 1913.90 284.40 0.24 MWD 6-axis 79 6952.49 29.66 283.55 93.94 6468.89 1959.87 486.66 -1898.89 1960.26 284.37 0.19 MWD 6-axis 80 7048.51 29.47 282.13 96.02 6552.41 2007.25 497.19 -1945.08 2007.62 284.34 0.76 MWD 6-axis 81 7142.56 29.16 281.73 94.05 6634.41 2053.28 506.71 -1990.14 2053.63 284.28 0.39 MWD 6-axis 82 7238.62 28.65 282.09 96.06 6718. 51 2099.70 516.29 -2035.57 2100.02 284.23 0.56 MWD 6-axis 83 7333.53 28.75 281.33 94.91 6801.76 2145.26 525.54 -2080.20 2145.56 284.18 0.40 MWD 6-axis 84 7428.93 28.65 281.22 95.40 6885.44 2191.05 534.50 -2125.13 2191.31 284.12 0.12 MWD 6-axis 85 7522.83 28.83 281.68 93.90 6967.77 2236.18 543.46 -2169.38 2236.41 284.06 0.30 MWD 6-axis 86 7617.45 28.71 281.59 94.62 .7050.71 2281.70 552.64 -2213.98 2281.91 284.02 0.13 MWD 6-axis 87 7712.87 28.21 281.00 95.42 7134.60 2327.14 561.55 -2258.57 2327.33 283.96 0.60 MWD 6-axis 88 7808.90 28.04 281.35 96.03 7219.29 2372.38 570.32 -2302.98 2372.55 283.91 0.25 MWD 6-axis 89 7904.60 27.99 281.61 95.70 7303.77 2417.31 579.27 -2347.03 2417.46 283.86 0.14 MWD 6-ax;s 90 8000.31 27.34 281.83 95.71 7388.54 2461.74 588.30 -2390.54 2461.87 283.83 0.69 MWD 6-axis ....-- - - - - - [(c)2001 Anadrill IDEAL ID6_1C_08]O 5 of 6 ANADRILL SCHLUMBERGER Survey Report 3-Jul-2001 14:40:46 page --- -------- ------ ------- ------ ====--=== ------- ========-~-== -------------- ----- ----- ------ -------- ------ ------ ------ ------- -------------- ------ Seq Measured Incl Azimuth Course TVD vertical Displ Di spl Total At DLS srv, Tool # depth angle angle length depth section +N/S- +E/W- di spl Azim (de,/ too qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100) type type -------- ------ ------- ------ ------- ------ --------------- --------------- ----- ----- ------ --- -------- ------ ------- ------ ----- --- ----------- --------------- ------ 91 8095.56 26.70 281.50 95.25 7473.39 2504.99 597.05 -2432.92 2505.11 283.79 0.69 MWD 6-axis 92 8190.72 25.99 282.01 95.16 7558.67 2547.21 605.65 -2474.27 2547.31 283.75 0.78 MWD 6-axis 93 8285.60 25.17 282.00 94.88 7644.25 2588.16 614.17 -2514.34 2588.26 283.73 0.86 MWD 6-ax;s 94 8381.32 24.39 282.55 95.72 7731.16 2628.28 622.70 -2553.54 2628.37 283.70 0.85 M\ND 6-axis 95 8476.90 23.43 282.27 95.58 7818.53 2667.01 631.02 -2591.37 2667.10 283.69 1.01 MWD 6-axis 96 8573.45 22.58 282.84 96.55 7907.40 2704.74 639.22 -2628.20 2704.82 283.67 0.91 MWD 6-ax;s 97 8668.68 22.26 283.08 95.23 7995.44 2741.06 647.37 -2663.60 2741.14 283.66 0.35 MWD 6-axis 98 8763.27 21.78 282.86 94. 59 8083.13 2776.52 655.33 -2698.16 2776.60 283.65 0.51 MWD 6-axis 99 8858.37 20.90 283.63 95.10 8171.70 2811.13 663.25 -2731.84 2811.20 283.65 0.97 MWD 6-ax;s 100 8953.94 20.30 284.13 95.57 8261.16 2844.75 671.31 -2764.49 2844.83 283.65 0.65 MWD 6-axis 101 9049.04 20.07 283.85 95.10 8350.42 2877.56 679..25 -2796.33 2877.64 283.65 0.26 MWD 6-axis 102 9144.69 19.69 285.58 95.65 8440.37 2910.08 687.50 -2827.79 2910.16 283.66 0.73 MWD 6-ax;s 103 9239.37 19.39 285.55 94.68 8529.60 2941.72 696.00 -2858.29 2941.81 283.69 0.32 MWD 6-ax;s 104 9335.01 18.24 284.15 95.64 8620.13 2972.55 703.92 -2888.10 2972.65 283.70 1.29 MWD 6-ax;s 105 9430.26 16.02 283.04 95.25 8711.15 3000.60 710.53 -2915.36 3000.70 283.70 2.36 MWD 6-ax;s 106 9525.44 14.56 282.82 95.18 8802.96 3025.70 716.15 -2939.82 3025.79 283.69 1.54 MWD 6-ax;s 107 9620.58 13.10 281.02 95.14 8895.34 3048.43 720.86 -2962.07 3048.52 283.68 1.60 MWD 6-axis 108 9715.10 11.79 281.84 94.52 8987.63 3068.79 724.89 -2982.03 3068.88 283.66 1.40 MWD 6-ax;s 109 9810.97 10.57 281.50 95.87 9081.68 3087.37 728.65 -3000.24 3087.45 283.65 1.27 MWD 6-ax;s 110 9905.24 9.57 282.33 94.27 9174.50 3103.85 732.05 -3016.37 3103.93 283.64 1.07 MWD 6-ax;s 111 9999.90 7.79 283.42 94.66 9268.07 3118.13 735.22 -3030.29 3118.21 283.64 1.89 MWD 6-ax;s 112 10016.77 7.72 284.06 16.87 9284.79 3120.41 735.76 -3032.51 3120.49 283.64 0.66 MWD 6-ax;s 113 10150.48 7.32 286.37 133.71 9417.35 3137.89 740.34 -3049..39 3137.98 283.65 0.37 MWD 6-ax;s 114 10244.93 6.52 285.12 94.45 9511.11 3149.26 743.44 -3060.34 3149.35 283.65 0.86 MWD 6-axis 115 10339.76 5.94 280.87 94.83 9605.38 3159.54 745.77 -3070.36 3159.63 283.65 0.78 MWD 6-ax;s 116 10434.55 5.74 287.32 94.79 9699.68 3169.17 748.10 -3079.70 3169.26 283.65 0.72 MWD 6-axis 117 10530.20 5.46 287.41 95.65 9794.87 3178.48 750.89 -3088.61 3178.57 283.66 0.29 MWD 6-ax;s 118 10624.93 5.27 288.02 94.73 9889.19 3187.31 753.58 -3097.05 3187.41 283.68 0.21 MWD 6-axis 119 10719.93 4.93 285.19 95.00 9983.81 3195.74 756.00 -3105.13 3195.84 283.68 0.45 MWD 6-ax;s 120 10814.37 4.77 290.86 94.44 10077.91 3203.69 758.46 -3112.72 3203.79 283.69 0.53 MWD 6-axis - - - [(c)2001 Anadr;ll IDEAL ID6_1C_08]O ANADRILL SCHLUMBERGER Survey Report 3-Jul-2001 14:40:46 page 6 of 6 --- -------- ------ ------- ------ ------- --- ---------------- --------------- ----- ----- ------ -------- ------ ------- ----- ----- ----- ----------- --------------- ------ Seq Measured Incl Az;muth Course TVD vertical Di sp 1 Displ Total At DLS srv, Tool # depth angle angle length depth section +N/S- +E/W- d;spl Az;m (de~S too qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100 type type --- -------- ----- ------- ------ -------- ------- ----------- --------------- ----- ----- ------ -------- ------ ------- ----- ------- ----- ---------- -------------- ------ 121 10909.06 4.35 293.37 94.69 10172.30 3211.12 761.29 -3119.69 3211.24 283.71 0.49 MWD 6-axis 122 11005.44 4.24 301.83 96.38 10268.41 3218.10 764.62 -3126.08 3218.23 283.74 0.67 MWD 6-axis 123 11101.13 4.28 312.13 95.69 10363.84 3224.58 768.88 -3131.73 3224.73 283.79 0.80 MWD 6-axis 124 11195.17 4.08 316.72 94.04 10457.63 3230.44 773.67 -3136.63 3230.63 283.86 0.41 MWD 6-ax;s 125 11289.54 3.87 320.39 94.37 10551.77 3235.78 778.57 -3140.96 3236.01 283.92 0.35 MWD 6-ax;s 126 11385.30 3.76 326.12 95.76 10647.32 3240.65 783.66 -3144.77 3240.94 283.99 0.41 MWD 6-ax;s 127 11420.14 3.59 324.63 34.84 10682.09 3242.31 785.50 -3146.04 3242.62 284.02 0.56 MWD 6-ax;s projected Survey at Total Depth: proj 128 11490.00 3.25 321.33 69.86 10751.83 3245.51 788.83 -3148.54 3245.85 284.07 0.56 [(c)2001 Anadr;ll IDEAL ID6_1C_08] I I I [ I I I I I I I I I I I I I I I BP Exploration NS-13 Formation Tops Formation Proposed Tops Actual Depths TVDss TVDrkb MDrkb TVDss TVDrkb MDrkb Top Pennafrost 1,149 1,205 1,205 1,149 1,205 1,205 Base Permafrost 1,499 1,555 1,555 1,499 1,555 1,555 SV6 - Top Confining Zone 3,009 3,065 3,075 3,009 3,065 3,075 Surface Casing Point 3,169 3225 3,245 3,138 3,194 3,215 SV5 - Base Confining Zone 3,286 3,342 3,371 3,286 3,342 3,365 SV4 3,602 3,658 3,728 3,602 3,658 3,728 SV2 -Top Upper Injection Zone 3,983 4,039 4,166 3,980 4,036 4,,206 SV1 - Top Major Shale Barrier 4,384 4,440 4,627 4,368 4,424 4,605 TMBK - Top Lower Injection Zone - Top Ugnu 4,739 4,795 5,035 4,714 4,770 5,000 M87F - Top Schrader Bluff - Base Ugnu 6,319 6,375 6,851 6,302 6,358 6,825 M60T - Base Lower Injection Zone (top Colville) 6,919 6,975 7,541 6,867 6,923 7,478 THRZ Top HRZ 8,614 8,670 9,445 8,564 8,620 9,335 BHRZ - Base HRZ 8,684 8,740 9,517 8,634 8,690 9,409 Top Kuparuk 8,764 8,820 9.600 8,699 8,755 9,480 Kuparuk C 8,952 9,008 9,791 8,886 8,942 9,669 Top Miluveach 9,264 9,320 10,104 9,149 9,205 9,937 Intermediate Casing Point 9,414 9,470 10,254 9,315 9,371 10,104 Intermediate Logging Point 9,414 9,470 10,254 9,315 9,371 10,104 Top Kingak 9,739 9,795 10,579 9,706 9,762 10,496 Geol Target #1 10,008 10,064 10,848 10,008 10,064 10,848 Top Sag River 10,698 10,754 11,538 10,665 10,721 11,471 Intermediate Casing Point 10,728 10,784 11,568 10,695 10,752 11,490 Top Shublik 10,793 10,849 11,633 Top Ivishak 10,873 10,929 11,713 Top Kavik 11,198 11,254 12,038 Totpal Depth 11,238 11,294 12,078 Lisburne 11,278 11,334 12,118 ¡ ( ~o 1---D5& bp ~";""."'.."...'..,',;,I,''.,i:!.')~I,,',',"','...,,'.",',',,",,', J!':' :;",' ~~IC Date: 12-05-2001 Transmittal Number:92349 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 NS13 11-20-2001 SCH 1 0 12000 DIRECTIONAL SURVEY; (HARDCOPY) DIRECTIONAL SURVEY; (DISKETTE) ~~ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center RECEIVED Attn: Ken Lemley MB3-6 Attn: Esther Fueg MB3-6 Attn: Lisa Weepie (AOGCC) Attn: Buford Bates (Murphy Exploration) Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) DEC 0 7 ¡r"ì1 Alaska Oil & Gas Cons. Commission Anchorage Petro technical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~'t l STATE OF ALASKA ( ALASKn JIL AND GAS CONSERVATION cOJh/'113SION APPLICATION FOR SUNDRY APPROVAL ~t~1 f1-" / I I/tik)/ K/~ l{) v~) I~'/ , I () I 1. Type of Request: D Abandon D Suspend D Plugging D Time Extension D Perforate D Alter Casing D Repair Well D Pull Tubing D Variance 181 Other D Change Approved Program D Operation Shutdown D Re-Enter Suspended Well D Stimulate Re-Enter Ops Shutdown 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: a Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (DF or KB) KBE = 56.19' 7. Unit or Property Name Northstar Unit 4. Location of well at surface 1169' NSL, 644' WEL, SEC. 11, T13N, R13E, UM At top of productive interval 1963' NSL, 3797' WEL, SEC. 11, T13N, R13E, UM At effective depth 1952' NSL, 3788 WEL, SEC. 11, T13N, R13E, UM At total depth 1956' NSL, 3791' WEL, SEC. 11, T13N, R13E, UM 12. Present well condition summary Total depth: measured true vertical 8. Well Number NS13 9. Permit Number 201-086 10. API Number 50- 029-23017-00 11. Field and Pool Northstar Unit Effective depth: measured true vertical 11490 feet 10752 feet 11405 feet 1 0667 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 161' 20" 3153' 13-3/8" 10039' 9-5/8" 1588' 7" Driven 1852 sx PF 'E', 470 sx 'G', 140 sx Lite 201' 3198' 201' 3177' 503 sx Econolite, 68 sx Lite, 400 sx 'G' 318 sx Class 'G' 10083' 9350' 9900' - 11488' 9169' - 10750' Perforation depth: measured None RECEIVED true vertical NOV 0 6 2001 Tubing (size, grade, and measured depth) None Alaska Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) None 13. Attachments a Description Summary of Proposal 0 Detailed Operations Program 15. Status of well classifications as: a Oil 0 Gas 0 Suspended 0 BOP Sketch 14. Estimated date for commencing operation November 17, 2001 16. If proposal was verbally approved Service Name of approver Date Approved Contact Engineer Name/Number: Allen Sherritt, 564-5204 17. I hereby certify that the~r~Oing is true and correct to the best of my knowledge Signed FI d H d 0 e ~ \ _. Title Senior Drilling Engineer oy ernan ez , , , " ",' " ,', , "CO'~Î11i~Si,~~Ø~e Or1~Y " Conditions of Approval: Notify Commission so representative may witness .5t:J;:JÖ ~\ ~t)'( ~~~ APproval No. 20" - "2 Plug integrity - BOP Test -L Location clàarance - --.) ...:::> Mechanical Integrity Test - Subsequent form required 10- \....\cY, ea.\~o N:>~\~Xt...~'\.~~o ~ \>«:>~~fê. Original Signed By ~~ \. ~~~Cl \ ~ Commissioner Date Submit In ripli ate Prepared By Name/Number: Sandra Sfewman, 564-4750 Date ( ( bp .,. ,\JI.'II. -......~ ~...- ~~- ~...-- ...'\ ~.... .'1''''.\. ". BP Exploration Alaska Inc. To: Tom Maunder - AOGCC Date: November 5, 2001 From: Allen Sherritt Northstar Operations Drilling Engineer Subject: Reference: NS13 Application for Sundry Permit - Re-Enter Suspended Well to complete drilling operations through the reservoir. Permit #201-086; API #50-029-23017-00 Sundry approval is requested for the re-entry of well NS-13. NS-13 was suspended for the 2001 broken-ice drilling restriction. The well was drilled/cased to the top of Sag River formation and suspended with a 9.7 ppg brine and 100' diesel cap. The well has been suspended since July 6th 2001. Re-entry into NS 13 is currently scheduled for Nabors 33E on November 1 ih, 2001. There is no required pre-rig work for this re-entry. All operations will be competed by Nabors 33E. Below is an outline of the proposed re-entry, production hole and completion operations. RiQ Operations: 1 . Nabors 33E is cu rrently positioned over NS-13. 2. Pressure test 9 5/8" casing x 7" drilling liner to 4500 psi surface pressure, (70% 7" drilling liner burst rating.) 3. Nipple down tree. Pull and lay down 4-1/2" tubing hanger from wellhead. Change out tubing spool adaptor for Fiber Optic modifications. Nipple up and test BOPE. 4. RIH w/ 6-1/8" casing scrapper and clean out to the 7" landing collar, -11 ,408'MD. Circulate 9.3 ppg mud into wellbore. POOH to cleanout assembly. 5. RIH w/ 6-1/8" bit, directional assembly and LWD. RIH to landing collar. 6. Drill out remaining cement. Drill 20' of new formation below 7" shoe with 9.3 ppg mud and perform a Formation Integrity Test to 11.3 ppg EMW. (FIT/LOT procedure on file with AOGCC). 7. Drill 6-1/8" production interval to TO at approximately 12079' MD / 11294' TVD. Condition hole for up coming open hole logging. POOH. 8. RU Schlumberger E-line unit and run open logs (GR/Res/Den/Neu/Sonic;RFT). POOH and RD Schlumberger. 9. Make a clean out run, if required, and condition the hole for a liner. POOH. 10. Run and cement the 4-1/2" 12.6# 13Cr liner. Set the liner hanger and liner top packer. Circulate off any excess cement. POOH with liner setting tool. 11. RIH with 3-3/4" cleanout assembly. Clean out to PBTD. Pressure test to 3400 psi for 30 minutes with a 9.3 ppg fluid to confirm the system integrity. 12. Displace well to 8.5 ppg seawater and monitor. POOH. 13. Run the 4-1/2", 12.6#, 13Cr Vam Ace completion assembly to the top of the 4-1/2" liner at +/-11338' MD. Run a GLM at 4500' TVD and a SSSV at 2000' MD. 14. Land the tubing hanger. 15. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. (' (" ~, 16. Displace annulus with inhibited seawater. 17. Set the packer. Pressure test the tubing and annulus to 4200 psi for 30 minutes. Shear the rupture disk in the GLM. Freeze protect with diesel to +/-4000' MD. U-tube diesel to tbg. side. 18. Install BPV. Rig down and move off. Attached Diagrams: Current suspended condition and the Proposed Completion. Allen Sherritt Alaska Drilling and Wells Operations Drilling Engineer 564-5204 TREE: ABB-VGI 5 1/8" 5ksi - WELLHEAD: ABB-VGI 13-5/8'( Multibowl 5ksi 133/8", 68#/ft, L-80, BTC @ 3197' 9-5/8" 47# L-80 BTM-C @ 10083' 7", 26#/ft L-80, BTC-M @ 11488' NS13 l" '1RIGINAL KB. ELEV = 55.77' 'i ,F. ELEV = 40.2' CB. ELEV = 15.57' 6.8 ppg Diesel Freeze Protection +1- 100'MD 9.7 ppg completion brine to TO of well @ 11488' MD DATE 1 0/25/01 REV. BY JAS Northstar WELL"NS13 API NO:50-029-23017 BP Exploration (Alaska) (I TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi 133/8", 68#/ft, L-80, BTC @ 3197' 4.5", 12.6#/ft, 13-Cr, Vam Ace TUBING 10: 3.958" CAPACITY: 0.01522 BBLlFT 9-5/8" 47# L-80 BTM-C @ 10083' 4.5" X NIPPLE, @ 11278" 3.813" ID 4.5" X NIPPLE, @ 11318' 3.813" ID 4.5" XN NIPPLE, @ 11328' 3.725" 10 4.5" WLEG, @ 11338' 3.958" ID 7", 26#/ft L-80, BTC-M @ 11488' PBTD @ 11998' TD @ 12078' NS13 DATE 1 0/25/01 REV. BY JAS ( RIGINAL KB. ELEV = 55.77' dF. ELEV = 40.2' CB. ELEV = 15.57' SSSV @ 2000' MD wi HXO SVLN nipple - 3.813" ID 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4000' 4.5" GLM @ 4500' TVD wi 3.833" ID - 7" LINER TOP @ 9900' - 7" PACKER,13 Cr @ 11298' 4.5" LINER TOP @ +1-11338' MD 4.5", 12.6#,13CrVam Ace Northstar WELL:NS13 API NO:50-029-23017 BP Exploration (Alaska) bp ,...YL" ',"" ,.',ii." ,""" ~~,~~7~;;;'\;'~~. :':: :'!? ~ f' ~ (' Date: 09-21-2001 Transmittal Number:92138 BPXA WELL DATA TRANSMITTAL Enclosed are the materials 1isted below. This data is being sent separate because of the confidential nature. If ou have an uestions, lease contact me in the PDC at 564-409 1 SW Name Date Contractor 0 De th Bottom De th Lo T e COMPOSITE PRINT (COR) NS13 06-16-2001 SCH 1,2,3,4 131 11451 TRUE VERTICAL DEPTH; COMPOSITE PRINT (COR) 06-16-2001 SCH 1,2,3,4 131 11451 MEASURED DEPTH LOG; COMPOSITE PRINT (AND) 06-16-2001 SCH 1,2,3,4 131 11451 MEASURED DEPTH LOG; COMPOSITE PRINT (AND) S13 06-16-2001 SCH 1,2,3,4 131 11451 RUE VERTICAL DEPTH; NS13 06-21-2001 SCH 169 11490 LWD,AND,CDR CD 1 EA c 4~, Lf)ø ~ Please Sign and Return on'e 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) RECE\VED SEP 2 S 2001 Alaska ou & Gas Cons. Commisskm Anchorage 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 REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 1. Operations performed: II Operation Shutdown 0 Stimulate 0 Plugging 0 Perforate 0 Pull Tubing 0 Alter Casing 0 Repair Well 0 Other 5. Type of well: 181 Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (OF or KB) KBE = 56.19' 7. Unit or Property Name Northstar Unit 99519-6612 4. Location of well at surface 1169' NSL, 644' WEL, SEC. 11, T13N, R13E, UM At top of productive interval 1963' NSL, 3797' WEL, SEC. 11, T13N, R13E, UM At effective depth 1952' NSL, 3788 WEL, SEC. 11, T13N, R13E, UM At total depth 1956' NSL, 3791' WEL, SEC. 11, T13N, R13E, UM 12. Present well condition summary Total depth: measured 8. Well Number NS13 9. Permit Number / Approval No. 201-086 10. API Number 50- 029-23017-00 11. Field and Pool Northstar Unit true vertical 11490 feet 10752 feet 11405 feet 1 0667 feet Plugs (measured) true vertical Effective depth: measured Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 161' 20" 31531 13-3/8" 10039' 9-5/8" 1588' 7" Driven 1852 sx PF 'E', 470 sx IG', 140 sx Lite 201' 31981 201' 3177' 503 sx Econolite, 68 sx Lite, 400 sx 'G' 318 sx Class 'G' 100831 93501 9900' - 11488' 9169' - 10750' Perforation depth: measured None RECEIVED true vertical AUG 0 6 ZOO1 Tubing (size, grade, and measured depth) None Alaska Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. ReDresentative Dailv Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge (~-~ ---------"-' SiQned sorota Stewmanjéjv~v Aoo.. ~~-;":" "- Title Technical Assistant _.- 16. Status of well classifications as: 181 Oil 0 Gas 0 Suspended Service Form 10-404 Rev. 06/15/88 Ur~IGlr~¡\L Date ()p) -- C)Z. ~ (':) t Prepared By Name/Number: Sandra Stewman, 564-4750 Submit In Duplicate ( (' BP EXPLORATION Page 1 ofB Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 6/14/2001 00:00 - 21 :00 21.00 Rig Released from NS-27 at 2100 hrs 6/14/01. 21 :00 - 00:00 3.00 MOB P PRE Moving rig from NS-27 to NS-13. 6/15/2001 00:00 - 05:00 5.00 MOB P PRE Finish moving rig from NS-27 to NS-13. Accept rig at 0500 hrs 6/15/01. 05:00 - 17:00 12.00 RIGU P PRE RIU supply lines between pipe rack and rig. Test G&I injection line to 4500 psi. OK. Charge supply lines with fluids into rig. Mix spud mud. Build berms around rig and service complex. Start NIU Hydril on diverter spools. Spot and RIU Schlumberger wireline unit and sheaves to run gyro. Spot rig mats and build ramp for forklift to put tools on pipe shed elevator. 17:00 - 18:00 1.00 RIGU P PRE Hold pre-spud meeting with Nabors night crew and service companies. 18:00 - 19:00 1.00 RIGU P PRE Hold pre-spud meeting with Nabors day crew. 19:00 - 22:00 3.00 RIGU P PRE Finish RIU riser between Hydril and flowline. Install and tighten turnbuckles on Hydril. Install mousehole. Finish RIU rig floor to PIU BHA. 22:00 - 23:00 1.00 RIGU P PRE Bring misc BHA X-O's and tools to rig floor. 23:00 - 00:00 1.00 RIGU P PRE PIU 13 3/8" hanger and drift through the Hydril and riser spools. RKB = 44.40' 6/16/2001 00:00 - 01 :00 1.00 DRILL P SURF BHA #1 - M/U 16" bit, X-O, stab, and 1 drill collar, and 1 stand of HWDP and GIH. 01 :00 - 02:00 1.00 DRILL P SURF Install derrick safety bar. This bar keeps the tugger lines from getting into the derrick board fingers. 02:00 - 03:00 1.00 DRILL P SURF Hang Schlumberger wireline sheaves for gyro. 03:00 - 04:00 1.00 DRILL P SURF Break circulation and pump through surface equipment and check for leaks. OK. 04:00 - 04:30 0.50 DRILL P SURF GIH and tag ice plug at 55' RKB. Drill through ice plug 10'-15' thick. POOH to HWDP. 04:30 - 07:00 2.50 DRILL P SURF BHA #1 - Continue PIU remaining drill collars and jars, GIH with HWDP. Tag up on gravel at 156' RKB. Wash down to 229'. Circulate out. Gyro at 100' 0.7 degrees Azimuth 143 150' 1.2 degrees Azimuth 145 200' 1.3 degrees Azimuth 140 05:30 - 07:00 1.50 DRILL P SURF Wash down from 156' to 229'. Circulate out. 07:00 - 11 :00 4.00 DRILL P SURF POOH with HWDP. M/U BHA #2 which includes orienting sub, . MWD, and jars. 11 :00 - 11 :30 0.50 DRILL P SURF Drill to -400'. 11 :30 - 00:00 12.50 DRILL P SURF Run gyro and MWD survey. Gyro - 270' 0.4 degrees Azimuth 145.8 MWD - 297' 0.24 degrees Drill ahead to 1105'. Discuss with Office. Decision made to drill ahead without gyro Printed: 7/9/2001 3:50:23 PM ( (' BP EXPLORATION Page 2 of 8 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase. Description of Operations 6/16/2001 11 :30 - 00:00 12.50 DRILL P SURF surveys from 371' until the MWD tool was free of magnetic interference (NS-10) at 1104'. This decision also included not surveying the section from 371' to 1104' with the gyro if the inclination stayed below 0.5 degrees until surface hole TO. The inclination in this section stayed below 0.2 degrees, so no gyro was run at 1104', and the azimuths were interpolated from the erroneous MWD azimuthal measurements. The max error in the bottom hole location using best-guess azimuths at 1104' is 5.1'. This was considered acceptable. The unknown azimuths for this interval will be measured at the surface hole TO by dropping a gyro. This gyro run at TO will also be used to qualify the MWD tool for JORPS. 6/17/2001 00:01 - 17:00 16.98 DRILL P SURF Drill from 1105' to 2824'. 17:00 - 18:00 1.00 DRILL P SURF Starting to see some fill on bottom. Pick up off bottom and circulate high vis sweep around. 18:00 - 00:00 6.00 DRILL P SURF Drill from 2824' to 3165'. ART 11.0 hours AST 3.9 hours 6/18/2001 00:00 - 01 :00 1.00 DRILL P SURF Finish drilling to 3215' MD TO. 01 :00 - 03:00 2.00 DRILL P SURF Pump high vis sweep and circulate out. 03:00 - 05:30 2.50 DRILL P SURF Round trip wiper trip to HWDP. One tight spot at 3108'. Max pull 30k over P/U. Work thru without top drive. GIH slick. No problems. No fill on bottom. 05:30 - 07:30 2.00 DRILL P SURF Circulate 2 bottoms up. Drop gyro and pump down slowly. Pump slug. 07:30 - 09:30 2.00 DRILL P SURF POOH to BHA. Hole slick. No problems. 09:30 - 12:00 2.50 DRILL P SURF Rack back BHA in anticipation of drilling NS-14 surface hole. Clean rig floor area. 12:00 - 13:00 1.00 CASE P . SURF M/U 13 3/8" casing hanger to landing joint section. LID hanger joint and hanger back in the pipe shed. 13:00 - 14:30 1.50 CASE P SURF RIU casing running tools. 14:30 -15:30 1.00 CASE P SURF Pre-job on running 133/8" casing. Perform a top drive and derrick visual inspection for loose bolt, pins, etc. No problems discovered. 15:30 - 21 :30 6.00 CASE P SURF Run a total of 79 jts 13 3/8" 68# L-80 BTC. FIS 3197.53' FIC 3155.41' UC 3112.94' ES Cementer 1608.28 Hole slick. No problems. 21 :30 - 22:00 0.50 CASE P SURF M/U hanger and two piece landing joints. SIO and land hanger. Final PIU 275k (includes 65k for top drive) Final SIO 220k (includes 65k for top drive) 22:00 - 00:00 2.00 CASE N SURF Back out casing fill-up tool from top drive. The casing fill-up tool was resting on the tool push plate on the top of the casing collar. At 2215 hrs a Floorhand was screwing a lifting eye into the top of the fill-up tool. During the operation an injury occured. The Injured employee was taken to the Northstar Medic. All drilling related activities were temporarily suspeneded pending further evaluation. 6/19/2001 00:00 - 01 :00 1.00 CASE N MISC SURF Finish accident review and hold PJSM for RID casing fill-up tool Printed: 7/9/2001 3:50:2:3 PM (' ( .,. BP EXPLORATION Page 3 of 8 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 6/19/2001 00:00 - 01 :00 1,00 CASE N MISC SURF and RlU cement head. 01 :00 - 01 :30 0.50 CEMT P SURF LID fill-up tool. RID Halliburton cementing head and cementing hose. 01 :30 - 04:30 3.00 CEMT P SURF Circulate and condition mud prior to cementing. 04:30 - 07:00 2.50 CEMT P SURF Pump 1 st stage cement job LEAD - Type L, 140 sks, 103 bbls, Wt 10.5, Yield 4.15 TAIL - Premium G, 2% CaCl, 470 sks, 96 bbls, Wt 15.9, Yield 1.15 Displacement 25 Seawater 441.3 bbls mud at 10 bpm with full returns. Bump plug. BPV's OK. Open ES cementer at 2200 psi 07:00 - 08:30 1.50 CEMT P SURF Circulate and condition mud between cement stages. Got-5 bbls from 1 st stage cement job after opening the ES cementer. 08:30 - 12:00 3.50 CEMT P SURF Pump 2nd stage cement TAIL - Permafrost E, 1853 sks, 716 bbls, Wt 12.0, Yield 2.17 Displacement 25 bbls seawater 215.9 bbls mud at 8 bpm with full returns Bump plug Close ES cementer with 1600 psi Check BPV's - OK 12:00 - 13:30 1.50 DRILL C SURF Develope procedure for RID Halliburton cementing head. 13:30 - 14:00 0.50 DRILL P SURF RID Halliburton cementing head. 14:00 - 15:00 1.00 DRILL C SURF Develope procedure for LID landing joint. 15:00 - 15:30 0.50 DRILL C SURF Hold planning meeting with all Drilling personnel concerning the revised forward plan from Anchorage office. 15:30 - 16:30 1.00 DRILL P SURF LID landing joint. Clear rig floor area. 16:30 - 17:30 1.00 DRILL P SURF Change from long to short bails. Change to drill pipe elevators. 17:30 - 19:30 2.00 DRILL P SURF PIU wash joint on drill pipe and wash out BOPS. 19:30 - 23:00 3.50 DRILL C SURF Show I orient new rig crew personnel around the rig while the investigation team conducted interviews. 23:00 - 00:00 1.00 DRILL P SURF LID 16" BHA tools and MWD. 6/20/2001 00:00 - 01 :00 1.00 DRILL P INT1 PJSM Walk around with new personnel. 01 :00 - 02:30 1.50 DRILL P INT1 Lay down BHA from 16" hole. 02:30 - 03:00 0.50 DRILL P INT1 PJSM 03:00 - 04:30 1.50 DRILL P INT1 Nipple down riser & diverter and set on NS-14. 04:30 - 05:30 1.00 DRILL P INT1 Nipple up tubing head adaptor. 05:30 - 10:00 4.50 DRILL P INT1 Nipple up BOP -Install choke & kill lines, turnbuckles, Koomey hoses. Install drilling sweep & valve. Function rams. 10:00 - 11 :00 1.00 DRILL P INT1 Install master bushings & iron roughneck track. Grease choke valve manifold & clean rig floor. 11 :00 - 11 :30 0.50 DRILL P INT1 PJSM 11 :30 - 12:00 0.50 DRILL P INT1 Install test plug & fill lines. 12:00 - 14:30 2.50 DRILL N WAIT INT1 UA test rig crews. 14:30 -15:00 0.50 DRILL P INT1 PJSM for testing BOP. Low to 250 psi for 5 min. & high to 5,000 psi for 10 min. 15:00 - 16:30 1.50 DRILL N SFAL INT1 Detected leaks. PJSM - Tighten stack I choke unibolts, packijng gland nuts on lockdown screws. Grease HCR kill line. Printed: 7/9/2001 3:50:23 PM ( (' BP EXPLORATION Page 4 of 8 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 6/20/2001 16:30 - 22:00 5.50 DRILL P INT1 Continue with BOP test. AOGCC Rep. Jeff Jones waived witness of the test. 22:00 - 22:30 0.50 DRILL P INT1 PJSM- Pull test plug & install wear ring. 22:30 - 23:00 0.50 DRILL P INT1 Back out test joint and Lay down. Blow down mud lines & top drive. 23:00 - 00:00 1.00 DRILL P INT1 PJSM - Service top drive 6/21/2001 00:00 - 01 :00 1.00 DRILL P INT1 Service top drive & install mousehole. 01 :00 - 01 :30 0.50 DRILL P INT1 PJSM for making up BHA. 01 :30 - 03:30 2.00 DRILL P INT1 M/U BHA # 3 - Orient MWD & Motor. 03:30 - 04:30 1.00 DRILL P INT1 RIH 04:30 - 05:00 0.50 DRILL P INT1 Wash down & tag ES cementer at 1608'. 05:00 - 05:30 0.50 DRILL P INT1 PJSM - Test casing to 1000 psi & hold for 5 min. 05:30 - 06:00 0.50 DRILL P INT1 Drill Out ES Cementer Note: PJSM -- Test Csg to 1000 psi for 5 minutes. 06:00 - 06:30 0.50 DRILL P INT1 RIH to cement above the landing collar. Note: Hit tight spot @ 2015' -- necessary to wash and rotate to get past this spot. 06:30 - 08:00 1.50 DRILL P INT1 Wash down to 3166' to top of cement. Circulate MWin = MWout = 9.2 ppg 08:00 - 09:00 1.00 DRILL P INT1 Test Casing to 2500 psi for 30 minutes -- Good Test. Note: Reviewed 01, D2 and 05 Drills with Rig Crews. 09:00 - 10:00 1.00 DRILL P INT1 Perform 05 Drill with Rig Crew -- BID Choke and Kill Lines. 10:00 -14:00 4.00 DRILL P INT1 Drill Cement and Float Track (LC,FC and FS) plus 30' of new formation to 3245' md. Note: Return mud was seriously clabbored up from cement contamination. Difference is sea water clorides are 2K VS. 19k normally -- probably Kuparuk River freshwater overrun. 14:00 - 14:30 0.50 DRILL P INT1 Circulate hole clean until MWin = MWout = 8.7 ppg. 14:30 - 16:00 1.50 DRILL P INT1 Perfom FIT -- 12.5 ppg EMW. Blow down choke and kill lines. 16:00 - 17:30 1.50 DRILL P INT1 PJSM -- Displace well to new drilling fluid. 17:30 - 00:00 6.50 DRILL P INT1 Drilling ahead while building from 21 degree to 30 degree to planned tangent. 6/22/2001 00:00 - 07:30 7.50 DRILL P INT1 Drlg f/3593' to 4256' md. Note: Finished build at 3611' md. 07:30 - 08:30 1.00 DRILL P INT1 Circulate Hi Vis Sweep and monitor well -- Static. 08:30 - 10:00 1.50 DRILL P INT1 Perform short trip to 13-3/8" casing shoe @ 3196' md. Note: 1) Stands 1 thru 4 pulled with no problems. 2) Stands 5 and 6 overpull 30k. 3) Stand 7 pulled 45K over and swab, wiped stand and eliminated swabbing. 4) Finished pulling stands 8-11 with no problem. 10:00 - 12:00 2.00 DRILL P INT1 Drlg f/4256' to 4510' md. 12:00 - 00:00 12.00 DRILL P INT1 Drlg f/4510' to 5116' md. Note: Sliding 30' every 400' to arrest a 1/3 deg/100' dropping tendency and a 1/2 deg/100' walking tendency to left. 6/23/2001 00:00 - 01 :00 1.00 DRILL P INT1 Drlg f/5116' -- 5209' md. Note: Pumped Hi-Vis Sweep at middle of stand down. 01 :00 - 01 :30 0.50 DRILL P INT1 Finish Circulating Hi-Vis Sweep -- monitor well -- Static. 01 :30 - 03:00 1.50 DRILL P INT1 Perform Wiper Trip. Note: Maximum Drag 25K, Avg Drag 5-10, Hole Fill Good. Printed: 7/9/2001 3:50:23 PM (" ( BP EXPLORATION Page 5 of 8 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 6/23/2001 03:00 - 12:00 9.00 DRILL P INT1 Drlg f/5209' -- 5781' md. 12:00 - 00:00 12.00 DRILL P INT1 Drlg f/5781' -- 6327' md. Note: Still sliding 25' per 500' drilled to arrest slight dropping and walking tendency. 6/24/2001 00:00 - 03:00 3.00 DRILL P INT1 Drlg. from 6327' to 6442' MD. 03:00 - 03:30 0.50 DRILL P INT1 Circulate - monitor well - pump slug. 03:30 - 06:30 3.00 DRILL P INT1 POOH. Hole slick. No problems. 06:30 - 07:00 0.50 DRILL P INT1 PJSM for LD BHA. 07:00 - 08:00 1.00 DRILL P INT1 UD BHA# 3. 08:00 - 08:30 0.50 DRILL P INT1 Download CDR & clean rig floor. 08:30 - 10:30 2.00 DRILL P INT1 PIU BHA # 4. Orient MWD & motor. Change bend on motor from 1.5 deg. to 1.15 deg. 10:30 - 11 :00 0.50 DRILL P INT1 Shallow test MWD & PJSM for PU ADN and source. 11 :00 - 12:00 1.00 DRILL P INT1 PIU ADN and load source. 12:00 - 14:00 2.00 DRILL P INT1 RIH with HWDP & 5" drill pipe. 14:00 - 15:00 1.00 DRILL P INT1 PJSM for cut & slip drilling line and man riding on tugger operation. 15:00 - 17:00 2.00 DRILL P INT1 Cut and slip 102' of drilling line. Inspect brakes & drawworks. 17:00 - 18:30 1.50 DRILL P INT1 PJSM - Service top drive & crown. 18:30 - 20:00 1.50 DRILL P INT1 RIH from 3140' to 6370'. Hole slick. No problems. 20:00 - 20:30 0.50 DRILL P INT1 Wash down from 6370' to 6442'. 20:30 - 00:00 3.50 DRILL P INT1 Drill and slide from 6442' to 6661'. 6/25/2001 00:00 - 00:00 24.00 DRILL P INT1 Drill from 6661' to 8800'. No hole problems. Planned depth for angle drop was 8750'. At 7850 allowed angle to start dropping while rotating and without sliding. This saved a good deal of sliding time. 6/26/2001 00:00 - 06:30 6.50 DRILL P INT1 Drill from 8800' to 9400'. 06:30 - 08:00 1.50 DRILL P INT1 Circulate bottoms up & monitor well. Pump slug. 08:00 - 10:30 2.50 DRILL P INT1 POH from 9400' to 6300'. Five intermittment tight spots from 7200' to 6450'. Able to work through without backreaming. 10:30 - 12:00 1.50 DRILL P INT1 RIH to 9328. Wash to bottom. No hole problems. 12:00 - 13:00 1.00 DRILL P INT1 Drill from 9400' to 9423'. 13:00 - 13:30 0.50 DRILL P INT1 Circulate out 6,000 units of gas. 13:30 - 00:00 10.50 DRILL P INT1 Drill from 9423' to 9725'. 6/27/2001 00:00 - 10:30 10.50 DRILL P INT1 Drill from 9725' to TO @ 10104' MD. 10:30 - 12:30 2.00 DRILL P INT1 Circulate hole clean. 12:30 - 13:00 0.50 DRILL P INT1 Monitor well & POH with 3 stands. Monitor well. 13:00 - 18:00 5.00 DRILL P INT1 Pump dry job & blow down all lines. POH to shoe. 18:00 - 18:30 0.50 DRILL P INT1 Monitor well & perform 0-1 drill. 18:30 - 20:00 1.50 DRILL P INT1 Continue POH. PJSM for laying down BHA. 20:00 - 21 :30 1.50 DRILL P INT1 PJSM- Lay down source & ADN. 21 :30 - 00:00 2.50 DRILL P INT1 Lay down BHA # 4. 6/28/2001 00:00 - 01 :00 1.00 DRILL P INT1 UD tools. Clean rig floor. 01 :00 - 01 :30 0.50 EVAL P INT1 PJSM for rigging up Schlumberger. 01 :30 - 02:30 1.00 EVAL P INT1 RIU wireline and Logging tools. Printed: 7/9/2001 3:50:23 PM ( ( BP EXPLORATION Operations Summary Report Page 6 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS13 NS13 DRILL +COMPLETE NABORS NABORS 33E Start: Rig Release: Rig Number: 33E 6/14/2001 Spud Date: 6/16/2001 End: Date From - To Hours Activity Code NPT Phase Description of Operations 6/28/2001 02:30 - 05:00 2.50 EVAL P INT1 RIH with PEX tool. Would not go past 5945'. Made four attempts. Landed at same depth. No problem picking up. 05:00 - 06:00 1.00 EVAL N INT1 POH. Install longer rubber extension on end of tool. Change three bottom standoffs from 9" to 6". 06:00 - 13:30 7.50 EVAL P INT1 RIH with PEX tool. Log from 9950' to 1400'. POH. 13:30 - 23:30 10.00 EVAL P INT1 RlU RFT, log #2. Took 22 pressure samples from 9843' to 9677'. Took two fluid samples at 9683' and 9761'. POH. RID Schlumberger. 23:30 - 00:00 0.50 BOPSUF N HMAN INT1 Prepare to test BOPs. RlU to drain stack through casing valve with rig 3" air pump. (Unable to drain into cellar because cellar needs to be resealed with impermeable coating.) Had leak between G&I and rig. Valve to drag chain in shaker room was plugged and a valve to the G&I was open but a valve inside the G&I was closed I pressuring the line between the rig and G&I. All hoses and clamps were in good condition. Rig had small amount of mud spray. Rig crew started cleaning spray on walls. ACS rep stated leak amounted to 40 gallons which included the water to clean the mud spray from the rig wall. Leak was called a 40 gallon non-process leak. All fluid was cleaned up and disposed of in G&I. 6/29/2001 00:00 - 00:30 0.50 BOPSUf; P INT1 PJSM on Testing BOPs 00:30 - 01 :30 1.00 BOPSUf; P INT1 Pull wear ring and install test plug 01 :30 - 02:30 1.00 BOPSUF P INT1 RIU to test BOPs. 02:30 - 10:30 8.00 BOPSUF P INT1 Test BOPs and choke manifold as per BP policy. 10:30 - 11 :30 1.00 BOPSUf; P INT1 RID test equipment and blow down choke and kill line. 11 :30 - 12:30 1.00 BOPSUF P INT1 Service Top Drive 12:30 - 13:30 1.00 EVAL P INT1 M/U BHA 13:30 - 17:30 4.00 EVAL P INT1 RIH. Fill DP every 3,000'. RIH. Tagged at 9926. 17:30 - 18:30 1.00 EVAL P INT1 Wash and ream to bottom. After 9926 took weight 4 times while reaming to bottom. No drag picking up. 18:30 - 21 :00 2.50 EVAL P INT1 Circulate B/U and condition mud. 21 :00 - 00:00 3.00 EVAL P INT1 Monitor well. POH 2 stands. Pump dry job. POH. 6/30/2001 00:00 - 02:00 2.00 EVAL P INT1 Continue POOH to 13-3/8" casing shoe. 02:00 - 03:00 1.00 EVAL P INT1 Monitor well and continue to POOH. 03:00 - 03:30 0.50 EVAL P INT1 Montior well and POOH with HWDP. 03:30 - 04:00 0.50 DRILL P INT1 PJSM -- LD BHA #5. 04:00 - 04:30 0.50 CASE P INT1 Clear rig floor. 04:30 - 06:00 1.50 CASE P INT1 PJSM -- Pump out stack with trash pump. Pull Wear Ring and Install test plug. 06:00 - 07:30 1.50 CASE P INT1 Change top set of pipe rams to 9-5/8" and test bonnet seals to 1000 psi. Pull test plug. 07:30 - 09:30 2.00 CASE P INT1 PJSM -- Rig up to run 9-5/8" intermediate casing. 09:30 - 00:00 14.50 CASE P INT1 PJSM -- Run 9-5/8" 240 joints of 9-5/8" casing. Notes: 1) 2 joints and landing joint left to run. 2) Hole started taking fluid while running last 25 stands -- slowed running speed to reduce losses. 3) No significant problems noted to this point -- hole in excellent condition. 7/1/2001 00:00 - 02:00 2.00 CASE P INT1 Run 9 5/8, 47#, L-80 casing. RlU Landing joint and hanger. Break circulation. Shut down pump. Land casing. Set at 10083' MD. Printed: 7/9/2001 3:50:23 PM ( ( BP EXPLORATION Page 7 of 8 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Activity Code NPT Phase Description of Operations 7/112001 02:00 - 04:30 2.50 CASE P INT1 RlU cement head. Circulate capacity of casing. Had PJSM for cementing casing. Established circulation at 1 BPM and increased to 10 BPM. 04:30 - 08:30 4.00 CEMT P INT1 Mix and pump cement as per program. See cement report. Displaced cement with mud pumps. Pumped calculated strokes (96%) efficiency plus 1/2 shoe track (8392 strokes). Plug did not bump. HOWCO flow meter showed 2 bbls difference from rig pumps. Check floats. OK 08:30 - 10:30 2.00 CASE P INT1 RID landing joint, cement equipment, tongs, change bails and drain stack. 10:30 - 12:00 1.50 CASE P INT1 Install 9 5/8 packoff. Test to 5,000 PSI 12:00 - 12:30 0.50 CASE P INT1 Rig down packoff running tool. 12:30 - 14:00 1.50 CASE P INT1 RIU lines to bullhead mud down 9 5/8 X 13 3/8 Annulus to flush annulus. 14:00 - 19:30 5.50 CASE P INT1 Pumped 192 bbls of 9.8 mud out of critical path. Remove 9 5/8 rams. Install VB rams. Test to 5,000 PSI. 19:30 - 22:00 2.50 CASE P INT1 Slip and cut 100' of drlg line. Service top drive and rig. 22:00 - 00:00 2.00 CASE P INT1 Lay down 8" BHA. 7/2/2001 00:00 - 01 :00 1.00 CASE P INT1 Finish LID BHA. 01 :00 - 04:00 3.00 CASE P INT1 MIU BHA # 6. 04:00 - 07:30 3.50 CASE P INT1 RIH to 9814'. Tagged cement. 07:30 - 08:00 0.50 CASE P INT1 Circulate and condition mud. 08:00 - 09:00 1.00 EVAL P INT1 Test casing to 3000 PSI. for 30 minutes. 09:00 - 09:30 0.50 EVAL P INT1 Conduct 0-5 drill. 09:30 - 11 :00 1.50 EVAL P INT1 Drill cement from 9814' to Float collar at 9997'. Test casing to 3000' for 10 minutes. 11 :00 - 12:30 1.50 DRILL P INT2 Drill out float equipment, cement and 20' of new hole to 10124'. 12:30 - 13:00 0.50 DRILL P INT2 Circulate and condition mud for LOT. 13:00 - 13:30 0.50 DRILL P INT2 Conduct LOT to 15.0 ppg EMW with 9.8 ppg mud. 13:30 - 17:30 4.00 DRILL P INT2 Circulate and condition mud. Raise mud weight to 11.3 ppg. 17:30 - 20:30 3.00 DRILL P INT2 Drill from 10124' to 10295'. 20:30 - 21 :30 1.00 DRILL N INT2 Repair #2 mud pump. 21 :30 - 00:00 2.50 DRILL P INT2 Drill from 10295' from 10411'. No hole problems. 7/3/2001 00:00 - 15:00 15.00 DRILL P INT2 Drill from 10411 to TO at 11490'. 15:00 - 16:30 1.50 DRILL P INT2 Criculate and Condition mud. 16:30 - 19:00 2.50 DRILL P INT1 Short trip to 9 5/8 shoe. No hole problems. 19:00 - 20:00 1.00 DRILL P INT2 Circulate BU for POH 20:00 - 00:00 4.00 DRILL P INT2 POH to 9 5/8 shoe. Drop rabbit. Pump dry job. Continue POH. 7/4/2001 00:00 - 03:00 3.00 DRILL P INT2 POH. 03:00 - 03:30 0.50 DRILL P INT2 PJSM for laying down BHA. 03:30 - 06:30 3.00 DRILL P INT2 LD BHA #6. 06:30 - 07:30 1.00 CASE P INT2 Rig up to run 7" liner. 07:30 - 08:00 0.50 CASE P INT2 PJSM for running 7" liner. 08:00 - 1:1 :00 3.00 CASE P INT2 Ran 39 joints of 7", 26#, L-80, Modified BTC liner. 11 :00 - 11 :30 0.50 CASE P INT2 Make up HMC liner hanger and ZXP liner packer. Liner set at 11488'. Top of liner at 9900'. 11 :30 - 12:00 0.50 CASE P INT2 Make up one stand of DP and circulate 1.5 times liner volume. 12:00 - 19:00 7.00 CASE P INT2 RIH with 7" liner on 5" DP to 9 5/8 shoe. 19:00 - 20:00 1.00 CASE P INT2 Make up Baker Cement head and set back on skate 20:00 - 21 :30 1.50 CASE P INT2 RIH with 7" liner on 5" DP to TO at 11490'. 21 :30 - 23:00 1.50 CASE P INT2 PU Baker cement head. Circulate and condition mud. Pumped 1 1/2 string volumes-- 375 bbls. Held PJSM for cementing liner. Printed: 7/9/2001 3:50:23 PM ( ( BP EXPLORATION Page 8 of 8 Operations Summary Report Legal Well Name: NS13 Common Well Name: NS13 . Spud Date: 6/16/2001 Event Name: DRILL +COMPLETE Start: 6/14/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: 33E Date From - To . Hours Activity Code NPT Phase Description of Operations 7/4/2001 23:00 - 00:00 1.00 CEMT P INT2 Begin cement job for 7' liner. 7/5/2001 00:00 - 01 :00 1.00 DRILL P INT2 Cemented liner as per program. See cement report. Displaced cement with rig pumps. Liner displaced with 9.7 ppb brine. 11.3 ppb mud above liner in 9518 casing. Bumped plug. Pressured to 3500 psi and set hanger. Checked floats. 01 :00 - 02:00 1.00 DRILL P INT2 Set packer and released from liner. Circulate BU. Had 5 bbls of cement returns. 02:00 - 03:00 1.00 DRILL P INT2 Test liner top to 15 ppg EMW plus 500 psi. Pressured to 2400 psi with 11.1 ppg mud. Held for 30 minutes. 03:00 - 05:00 2.00 DRILL P INT2 Reverse circulate above liner top and displace with high vis pill and 9.7 ppg brine. 05:00 - 07:30 2.50 DRILL P INT2 Rig down reverse lines. RID cement head and lay down same. 07:30 - 10:30 3.00 EVAL P INT2 POH with DP and setting tool. 10:30 - 16:00 5.50 EVAL P INT2 Made decision to break all connections and re-dope connections prior to cold stacking rig. Continued POH. 16:00 - 00:00 8.00 EVAL P INT2 RIH with stands from derrick. POH. Break and re-dope all connections. 7/6/2001 00:00 - 05:00 5.00 DRILL P INT2 POH with DP. Break and re-dope all connections. 05:00 - 06:00 1.00 DRILL P INT2 Pump diesel in top 100' of 9 5/8 06:00 - 07:00 1.00 DRILL P INT2 Clean rig. Pull wear ring. Found damaged threads in TWC profile in Tubing Hanger. Attempt to repair on location. 07:00 - 07:30 0.50 DRILL P INT2 PJSM on changing rams. 07:30 - 09:30 2.00 DRILL P INT2 Change top set of pipe rams to 2 3/8. 09:30 - 12:00 2.50 DRILL P INT2 Send tubing hanger to Baker in Deadhorse for repair. Service top drive. Change out saver sub on Top Drive to 2 3/8. 12:00 - 16:30 4.50 DRILL N INT2 Wait on tubing hanger. Load pipe shed with 13 3/8 casing in preparation for cold stacking. 16:30 - 18:30 2.00 DRILL P INT2 Install tubing hanger and test to 5000 PSI 18:30 - 19:30 1.00 DRILL P INT2 Remove bottom 5" ranis and install 2 3/8 rams 19:30 - 00:00 4.50 DRILL P INT2 Nipple down BOPs Printed: 7/9/2001 3:50:23 PM bp ,,~ :: ..~~ .L.:.;.',.,,:,',,~,""'.':. ..-,,'~... (' ( 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. Top Lo Run De th Bottom De th Lo T e 1 199 11490 FORMATION EVALUATION MUDLOG; 1 :600 SCALE (MD) FORMATION EVALUATION MUDLOG; 1 :600 SCALE (TVD) FORMATION EVALUATION MUDLOG; 1 :240 SCALE (MD) FORMATION EV ALUATION MUDLOG; 1 :240 SCALE (TVD) WELL COMPLETION REPORT WELL COMPLETION REPORT; END OF WELL REPORT; SW Name Date Contractor .0\- Cf6lD NS13 06-16-2001 SPERRY NS13 06-16-2001 SPERRY 1 199 11490 NS13 06-16-2001 SPERRY NS13 06-16-2001 SPERRY 0 \ .,"OløO NS31 05-21-2001 STATE OF ALASKA '1)\ -"0 t,t' NS29 06-18-2001 STATE OF ALASKA I--()ßl.p NS13 06-16-2001 SPERRY 7p SPERRY NS13 06-16-2001 199 11490 1 199 11490 1 199 11490 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) AID S71fr~ ~~,ør~ /Þ ,S1Jf 7 ê Itt:~'¡ FORMATION EV ALUATION MUDLOG; (DISKETTE) RECEIVED AUG 0 2 2001 AIæka Ofl & Gas Cons. Commission Anchomge Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ? D , ...D€& .... .D1....-t)'"2"1 of, ( Date: 06-26-2001 Transmittal Number:92183 (' bp Ö.'i' -i:,",.,:,'.,',..,'".,",,~',',l;i ,.,,~ -.. CONfEOtNTIAL 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 ~13 06-28~2001 SCH 1 3197 9950 PLATFORM EXPRESS; VI DENSITY /NEUTRON LOG; ~S13 06-28-2001 SCH 1 3197 9950 PLATFORM EXPRESS; v HIRES LATERAL ARRAY LOG; þJ513 06-28-2001 SCH 1 9677 9843 REPEAT FORMATION '\,; TESTER; NS13 06-28-2001 SCH 1 3197 9950 DIPOLE SHEAR SONIC v IMAGER; NS13 06-28-2001 SCH 1 160.0 9950.0 LDWG PEX; DSI; HRL; (CD) " NS13 07-03~2001 ANA 1 0 11490.0 SURVEY REPORT; HARDCOPY /DISKETTEE; \ \ NS13 07-12-2001 - - - - APPLICATION FOR )t SUNDRY APPROVAL; NS27 05-28-2001 SCH 1 0 11390 TEMPERATURE LOG; Y'" ~ NS27 07-15-2001 SCH 1 10644 11336 PERFORATION RECORD; ¡/v NS27 05-28-2001 SCH 1 7952 10975 DIPOLE SHEAR SONIC ....... IMAGER; ./ NS27 05-29-2001 SCH 1 62.0 10927.0 DIPOLE SHEAR SONIC IMAGER;/ TEMPERATURE LOG; (CD) ~'\D ~e pClt-fS ~~We. Please Sign and- eturn one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center RECEIVED JUL 2 7 2001 Alaska Oil & Gas Cons. Commilsion Anchorage -"'-."" Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 .f,-" ( bp ~.....,..,.,...~.~,...t.:..,'¡I:\,....,..'.....". :t .~'.. 1tf..- (' Date: 06-26-200 I Transmittal Number:92 I 83 BPXA WELL DATA TRANSMITTAL 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 RECEIVED JUl 2 1 2001 Alaeka Oil & Gas Cons. Commi88ion Anchorage bp L' (.. Date: 06-26-2001 Transmittal Number:92182 ,t~'~l ~;¡~tti;J. '.'. ......~.;".'1:"'.. ...,,~ 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. 7,ò \ ,otÞD Top SW Name Date Contractor Loq Run Depth Bottom Depth Loq 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 INTERPRET A TION; QC PLOT-DSI; SONIC PROCESSING; NS31 05-12-2001 SCH 1 198.0 10945.00 LWD;AND;CDR; (CD) 2Dl- {jtß ~o\ ... c1ll 20\ ~oßI.o RECEIV:ED JUL 2 6 2001 lease Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Aiaska Oil & Gas Cons. CommÏl8iOn Anchorage Attn: Ken Lemley MB3-6 Attn: Tim Putnam MB3-6 Attn: Buford Bates (Murphy Exploration) Agn:,ij()wÇ1Jd.Ql<-l~ndCAOGCC) 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 l ALASKA ùlL AND GAS CONSERVATION COM~,."SION APPLICATION FOR SUNDRY APPROVAL ,ðV1¡\ W 4Ì1i 1(,1] ~k. Cor 1. Type of Request: 0 Abandon 0 Suspend 0 Plugging 0 Time Extension 0 Perforate 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Variance 0 Other 0 Change Approved Program 1m Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate 14. Estimated date for commencing operation July 5,2001 16. If proposal was verbally approved Julie Heusser 7/3/2001 Name of approver Date Approved Contact Engineer Name/Number: Steve Chesher, 564-4196 17. I ~ereby cerqfy,that the .1qçego)pg is true and correct to the best of my knowledge Signed FI ~d H lV~d ~'\ -Iè l. Title Senior Drilling Engineer oy eman ez 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 11691 NSL, 6441 WEL, SEC. 11, T13N, R13E, UM At top of productive interval 1969' NSL, 4067' WEL, SEC. 11, T13N, R13E, UM (As Planned) At effective depth N/A At total depth 2024' NSL, 4302' WEL, SEC. 11, T13N, R13E, UM (As Planned) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11490 feet 1 0752 feet feet feet Casing Structural Conductor Surface Intermediate Production Liner Length Size 161' 20" 3153' 13-3/8" 10039' 9-5/8" 1588' 7" Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments ~ Description Summary of Proposal 5. Type of well: 181 Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (DF or KB) Planned RKB = 55.77' 7. Unit or Property Name Northstar Unit 8. Well Number NS13 9. Permit Number 201-086 10. API Number 50- 029-23017 11. Field and Pool Northstar Unit Plugs (measured) Junk (measured) Cemented MD TVD Driven 201' 201' 1852 sx PF 'E', 470 sx 'G', 140 sx Lite 3197' 3177' 503 sx Econolite, 400 sx Class 'G' 10083' 9350' 317 sx Class 'G' 9900' - 11488' 9169' - 10750' RECEIVED JUL 0 5 2001 Alaska Oil & Gas Cons. Commission Anchorage 0 Detailed Operations Program 15. Status of well classifications as: ~ Oil 0 Gas 0 Suspended 0 BOP Sketch Service Prepared By Name/Number: Sondra Stewman, 564-4750 Date '1/Ç/DI Conditions of Approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance - Mechanical Integrity Test - Subsequent form required 10- ..¡.() 4- ORIGINAL SIGNED By 0 Ta lor Seamount OR\G Commissioner ( (' Stewman, Sandra D Subject: Chesher, Steve W Tuesday, July 03, 2001 5:35 PM Stewman, Sandra 0; Hubble, Terrie L; NSU, ADW Drlg Rig 33E Cocking, David A; Hernandez, Floyd; Krieger, Andy G; Holt, Barbara M; Bill, Michael L; Francis, Michael J; Lemley, Kenneth R FW: NS13 & NS27 From: Sent: To: Cc: Here is AOGCC approval for the forward plan. Sondra and Terrie, please see Julie's note about submission of a 10-403 form by p.m. Thursday. Thanks to all for all the help. Steve Chesher - BP Alaska (907)564-4196 - phone (907)564-5200 - fax (907)240-8039 - cell -----Original Message----- From: Julie Heusser [mailto:julie_heusser@admin.state.ak.us] Sent: Tuesday, July 03, 2001 4:35 PM To: Chesher, Steve W Cc: Tom Maunder Subject: Re: NS13 & NS27 Hello Steve, I understand that the "Temporary Abandoment" procedure is for well NS 13 and not NS 29 as specified on the e-mail. I further understand that this temporary abandonment procedure is the same that was used on NS 27 and NS 29. You have verbal approval to proceed with the temporary abandonment of well NS 13. Please submit a 10-403 by the end of the day on Thursday, July 5 with the necessary information. Per discussion among staff, we believe that the proposed work to remove the ice plug from well NS 27 could reasonably be covered by the original permit to drill, as the well is not yet perforated. Please submit a 10-407 when the well has been perforated. I also understand that BP intends to move the well back to NS 13 and stack the rig for the season. Regards Julie Heusser "Chesher, Steve W" wrote: > Julie, > Here is the requested procedure for the NS27 wellwork. I have also included > the NS13 temporary abandonment procedure for your review (I e-mailed this to 1 ;"" > Tom but realize he is away 0; vacation). Our current plan is to run C.d > cement the i' liner for the NS13 on Wednesday. We will perform the temporary > abandonment and move the rig to NS27 on Thursday. The estimated time to move > the rig, perform the NS27 wellwork and move the rig back to NS13 is 3 days. > We will cold stack the rig on NS13 for the drilling hiatus while the > production modules are installed. > > Please call me with verbal approval and we will follow up after the July 4 > holiday with Sundry notices. > > Thanks. > ("3 ~'-- > NS.~emporary Abandonment > 1. Pump i' cement. > 2. Drop DP wiper plug. > 3. Displace with a volume of 9.7 ppg brine to displace the i' liner. > 4. Pump a volume of 11.3 ppg mud to displace the DP. Land the liner wiper > plug. Check floats. > 5. Set the liner hanger and liner top packer. > 6. Pull out of the liner. > 7. Circulate the excess cement off the liner with 11.3 ppg mud. > 8. Pressure test the liner to 500 psi over the 9-5/8" frac gradient. > 9. Displace the 9-5/8" casing to 9.7 ppg brine. > 10. POOH wi the liner setting tool. Top off the well with a 100' cap of > diesel or mineral oil. > 11. Run the tubing hanger with TWC in place. > 12. Nipple down the BOP. > 13. Nipple up the tree and test to 5000 psi. > 14. Pressure test the TWC from below to 1000 psi. > 15. Move the rig to NS27. > > NS27 Wellwork > Well NS-27 was drilled in February of 2001 as an Ivishak pre-produced > injection well. When attempting to run in the hole to perforate, > Schlumberger wireline hit an ice plug. Many attempts have been made to > break down the ice plug with wireline brushes, etc. as well as dump bailing > methanol. All attempts failed. The following rig procedure outlines rig > operations to allow full tubing access. > > Rig Operations: > > 1. MIRU Nabors 33E, ND tree and NU BOPE and test to 3000 psi. > 2. Circulate out freeze protection and displace well to > seawater. > 3. Clean out ice plug in tubing. > 4. Circulate to freeze protect from 4000' MD. > 5. RDMO Nabors 33E. > > Steve Chesher - BP Alaska > (907)564-4196 - phone > (907)564-5200 - fax 2 > (907)240-8039 - cell ( (' 3 I ~1f~1fŒ (ill~ iA\~~~[K(~ ~, AI/ASIiA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 w. ""fTH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Floyd Hernandez Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK. 99519-6612 Re: Northstar Unit NS 13 BP Exploration (Alaska) Inc. Permit No: 201-086 Sur Loc: 1169' NSL, 644' WEL, SEC. 11, TI3N, RI3E, UM Btmhole Loc. 2024' NSL, 4302' WEL, SEC. 11, TI3N, RI3E, 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. Annular disposal has not been requested as part of the Permit to Drill application for NS 13. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. 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 at659-3607. Sincerely, JtdLv AA I ~~ Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this 5~ day of June, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/oencl. Department of Environmental Conservation w/o encl. f STATE OF ALASKA ,,- ALASKÄ vlL AND GAS CONSERVATION COM~...:)SION PERMIT TO DRILL 20 AAC 25.005 ~6 1 a. Type of work II Drill 0 Redrill 11 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (OF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned 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) 1169' NSL, 644' WEL, SEC. 11, T13N, R13E, UM Northstar Unit At top of productive interval 8. Well Number 1969' NSL, 4067' WEL, SEC. 11, T13N, R13E, UM NS13 Number 2S100302630-277 At total depth 9. Approximate spud date 2024' NSL, 4302' WEL, SEC. 11, T13N, R13E, UM OS/20/01 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 312808,3784' MD (Approx) NS10, 16.54' away at 800' MD 4472 12079' MD / 11294' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 2300' MD Maximum Hole Angle 240 Maximum surface 4106 psig, At total depth (TVD) 11238' / 5230 psig 18. Casing Program Specifications Setting Depth Size TOD Bottom Quantitv of Cement Hole Casina Weiaht Grade CouDlina Lenath MD TVD MD TVD (include staae data) 20" 20" 169# X-56 WELD 161' Surface Surface 201' 201' Driven 16" 13-3/8" 68# L-80 BTC 3205' Surface Surface 3245' 3225' 1966 sx PF 'E', 470 sx Class 'G' 12-1/4" 9-5/8" 47# L-80 BTC-Mod 1 0041 ' Surface Surface 1 0081' 9470' 593 sx Econolite, 470 sx Class 'G' 8-1/2" 7" 26# L-80 BTC-Mod 1589' 9931' 9332' 11520' 10783' 283 sx Class 'G' 6-1/8" 4-1/2" 12.6# 13Cr Vam Ace 708' 11370' 10862' 12078' 11294' 112 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measu red 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 RECEIVED Production Liner MAY 0 8 2001 Perforation depth: measured Alaska Oil & Gas Cons. Commission Anchorage true vertical 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Chesher, 564-4196 Prepared By Name/Number: Sandra Stewman, 564-4750 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Floyd Hernandez~..I I" --- Title Senior Drilling Engineer Date 5/'S; () I I' ", ,>' :.': ,', '; ,.." '." ',;:Z: ,,' ',:.,':.,:,! ': "" >"0 " ";'::::; ':",';:,::-.¡';.:'; :;, ' ..' '" '. "':":::::', ' , , ' '.' ,'" , , '" ..;' ':, ,': ';' ~:, '.', ;.:,;0::,/, "',:,,',CommitSE jiq,fI":lJ$~' n:ly:-: ',I, ,,>", ",,>'{'<";:' :,,' .. ':", ,,' '::::".;""",,,:,, ," :':", Permit Number 1 API Number 1 { ~r~ïA D1e 1 See cover letter <.01- 0 r¡c; 50- 002.-.9 - Z so/? for other requirements Conditions of Approval: Samples Required DYes ßNo Mud Lo~ Re~uÌÍ"edJ 0 Yes ŒlNo Hydrogen Sulfide Measures DYes ENo Directional Survey Required ~Yes DNo Required Working Pressure for BOPE D2K D3K 0 4K~5K D10K D15K 0 3.5K psi for CTU Other: ( () / e:/Ò/ (ðRDG~NAl SIGNED tdJ~ by order of Approved By "ß M. Heusser , ~, ! ,~CQmmissioner the commission Date Form 10-401 Rev. 12-01-85 t)., t t:,} ~ It\\"~ r\L Submit!¡n Triplicate NS13 Permit to Drill (" ( I Well Name: Well Plan Summary INS13 I Type of Well (producer or injector): I Producer Northstar Slot: NS13 Surface Location: 1169'FSL,644'FEL,Sec.11,T13N,R13E,UM X = 659831 Y = 6030941 Target: 1969' FSL, 4067' FEL, Sec. 11, T13N, R13E, UM 250' Radius X = 656391 Y = 6031669 10754' TVDrkb Bottom Hole Location: 2024' FSL, 4302' FEL, Sec. 11, T13N, R13E, UM X = 656155 Y = 6031718 11294' TVDrkb I AFE Number: 1831307 I Estimated Start Date: I May 22,2001 I I Rig: I Nabors 33E I Operating days to complete: I 26 EJ 12079' I I TVDrkb: 111294' I 55.771/ 15.67' I Well Design (conventional, slimhole, etc.): I Modified Big Bore I Objective: I Ivishak Producer Mud Program: s S dM d 16" HIS Surface Hole Mud Properties: eawater ¡PU u oe ectlon From Surface to ~3245' MD / 3225' TVD (~150' TVD below top SV6). Interval Density Viscosity YP Tauo Gel APIFL 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. d' HIM d P I h'b't d KCI 12 1/4" HIS r nterme late oe u ropertles: n I I e - oe eClon From Surface Casing Shoe to 10881' MD / 9470' TVD (~top Miluveach). Interval Density (ppg) PV YP Tauo API! pH HTTP FL Initial 9.0- 9.5 10 - 25 20 - 28 4-7 6-10 8.5 - 9.5 Top HRZ 9.6 10 - 25 20 - 25 4-7 4-6/<10 8.5 -9.5 Top Kuparuk 9.8 10 - 25 20 - 25 4-7 4-6/<10 8.5 -9.5 to Miluveach 1 NS13 Permit to Drill ( (" Drillin Liner Hole Mud Properties: Inhibited KCL 8-1/2" Hole Section From Intermediate Casing Shoe to 11520' MD / 10784' TVD (top of Sag) Interval Densit PV YP Miluveach & 11.3 10 - 25 20 - 25 Kingak to top of Sa Tauo 4-7 API FL 4-6/<10 H 8.5 - 9.5 Production Hole Mud Properties: Seawater/Barite/CaC03 Drill-In Fluid From Intermediate Casing Shoe to 12079' MD / 11294' TVD Interval Densit PV YP Initial/Final 9.3 10 - 25 20 - 25 6-1/8" Hole Section Tauo 4-7 Di rectional: (P6) KOP: :t2300' MD Cantenary curve 2.5°/100' build Maximum Hole Angle: :t24.06° - Slant Well Close Approach Well: Surface- 30' well spacing with NS10- 16.54' displacement at 800' MD. Gyro will be used for initial surveys and kickoff Survey Program: Gyros as required from surface to +/- 1000'. Standard MWD surveys from +/- 1000' to TD. Logging Program: 16" Section: Drilling: GR/Directional Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples.(100' intervals), CFM (connection flow monitorinq) Open Hole: None Cased Hole: None 12-1/4" Section: Drilling: GR/Directional, Res, Den, Neu, PWD, Isonic Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals down to 8910' TVDrkb; thereafter, 40' intervals - 20' intervals at shows), Geochem samples from 8910' TVDrkb (40' intervals - 20' intervals at shows), CFM (connection flow monitorinq) Open Hole: None Cased Hole: None 8-1/2" Section: Drilling: GR/Directional, Res, Den, Neu, PWD, Isonic 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 monitorinq) Open Hole: None Cased Hole: None 6-1/8" Section: Drilling: None 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 monitorina) 2 NS13 Permit to Drill ( ( Open Hole: Quad Combo GRJRes/Den/Neu/Sonic, RFT ressures onl Cased Hole: None Formation Markers: Formation Tops MD TVDss Pore EMW (ppg) Comments Pressure (psi) Top Permafrost 1205 1149 517 8.65 Base Permafrost 1555 1499 674 8.65 SV6 3076 3009 1353 8.65 Set surface casing 150' tvd below top of SV6 SV5 3371 3286 1478 8.65 SV4 3717 3602 1620 8.65 SV2 4134 3983 1791 8.65 SV1 4573 4384 1972 8.65 Top Ugnu (UG4A) TMBK 4962 4739 2131 8.65 Top Schrader 6692 6319 2842 8.65 Top Seabee (CM3) 7349 6919 3112 8.65 Colville Shales Top HRZ 9205 8614 3874 8.65 Base H RZ 9282 8684 3906 8.65 Top Kuparuk 9370 8764 4233 9.29 Top Kuparuk C 9576 8952 4333 9.31 Top Miluveach 9917 9264 4395 9.12 Set intermediate casing into the top of the Miluveach Top Kingak 10437 9739 4690 9.26 Top Sag River 11488 10698 4979 8.95 Set drilling liner into the top of the SaQ River to cover up the Kingak Top Shublik 11592 10793 5023 8.95 Top Ivishak 11679 10873 5060 8.95 Top Kavik 12035 111 98 5212 8.95 Proposed TD 12079 11238 5230 8.95 Top Lisbu me 12122 11278 5249 8.95 C IT b8 p aSln~ u Ing rogram: Hole Size Csg/ Wt/Ft Grade Conn Casing Casing Top Hole Btm Tbg O.D. Length M DITVDrkb MDfTVDrkb 20" 20" 169# X-56 WELD 161' Su rface 201 '/201' 16" 13 3/8" 68# L-80 BTC 3205' Su rface 3245' /3225' 12 1/4" 9 5/8" 47# L-80 BTC-Mod 1 0041' Surface 10081 '/9470' 8 Y2" 7" 26# L-80 BTC-Mod 1589' 9931 '/9332' 11520'/10783' 6-1/8" 4-1/2" 12.6# 13Cr Vam Ace 708 11370'/10862 12078'/11294' Tubing 4-1/2" 12.6# 13Cr Vam Ace 11330' Su rface 11370'/10862' Cement Calculations: The followin cement calculations are based upon a two stage job using a stage tool. Casin 13-3/8" Surface Basis: Stage 1: Lead: Based on 895' of 16" open hole x 13 3/8 " csg. with 50% excess. Lead TOC: -1600' 3 NS13 Permit to Drill (' ( Tail: Based on 750' of 16" open hole x 13 3/8" csg. with 50% excess + 80' shoe joint. Tail TOG: At -2495' MD 2495' TVD Stage 2: Lead: Based on 1600' of 16" open hole x 13-3/8" csg. with 250% excess + csg capacity. Lead TOG: Surface Sta e 1: Total Cement I S acer Tail 10 bbls sea water 50 bbl AI ha S acer wei hted to 1.0 342 bbl I 593 sk of 11.2 ppg Econolite. 3.24 dIsk, BHST 1950 I BHCT 1350, TT = 4.0 hrs 96 bbl I 470 sk of 15.9 ppg Premium 'G'. 1.15 disk, BHST 1950 I BHGT 1350, TT = 4.0 hrs over mud MW Tail 4 NS13 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. Oiverter, BOPE, and drilling fluid system schematics on file with AOGCC. Intermediate Section: . Maximum anticipated BHP: 4333 psi @ 8952' TVOss - Kuparuk . Maximum surface pressure: 3438 psi @ surface (based on BHP and a full column of gas from TO @ 0.10 psi/ft) Drilling Liner Section: . Maximum anticipated BHP: 4993 psi @ 10728' TVOss - Sag River . Maximum surface pressure: 3920 psi @ surface (based on BHP and a full column of gas from TO @ 0.10 psi/ft) Production Section: . Maximum anticipated BHP: 5230 psi @ 11238' TVOss - Total Depth . Maximum surface pressure: 4106 psi @ surface (based on BHP and a full column of gas from TO @ 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, the NS27 or the NS29 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 NS13 except for surface proximity to NS10. NS10 has 16.54' of separation at 800' MD. NS13 passes anticollision criteria with all wells identified as a "major risk." Gyros will be run from surface to -1000' MO or until reliable MWO 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 (0-3225' TVO) 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. 5 NS13 Permit to Drill ( (' . 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-established. Be sure to 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, NS29 and NS31 have not experienced hydrates. Mudloggers will be used continuously on NS13 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, NS27, NS29 or NS31. Mudloggers will be used continuously on NS13 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. However, 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. . 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. . The kick tolerance for the 12 1/4" open hole section would be 50 bbls assuming an influx from the Kuparuk interval at -9370' MD I 9008' TVD. This is the worst case scenario based on a 9.81 ppg (0.5 ppg over the known pore pressure) pore pressure gradient, a fracture gradient (based on a FIT) of 12.5 ppg at the 13-3/8" shoe, and 9.8 ppg mud in the hole. . DRilliNG liNER SECTION: Mudloggers will be rigged up throughout the entire section. The directional targets have been defined to avoid drilling into faults in this hole section. So, faults are not expected. However, 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. 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. . . 6 NS13 Permit to Drill ( f . 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. With the 9-5/8" casing set into the top of the Miluveach, this should allow higher mud weights to be used (as required) in this hole section. . 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. . The kick tolerance for the 8-1/2" open hole section is infinite (due to limited amount of open hole) assuming an influx from the Sag River interval at -11520' MD / 10784' TVD. This is the worst case scenario based on a 9.45 ppg (0.5 ppg over the known pore pressure) pore pressure gradient, a fracture gradient of 12.5 ppg at the 9-5/8" shoe, and 11.3 ppg mud in the hole. 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 drilling liner shoe will be drilled out with the 11.3 ppg mud. The mud will then be displaced with a 9.3 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 (CaC03) will be maintained in the system. Severe lost circulation was encountered on the NS29. 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 6-1/8" open hole section is infinite (due to the limited amount of open hole) assuming an influx from TD at -12079' MD / 11294' TVD. This scenario is based on a 9.45 ppg (0.5 ppg over the known pore pressure) pore pressure gradient, a fracture gradient of 11.3 ppg (based on FIT) at the 7" shoe, and 9.3 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. 7 NS13 Permit to Drill (' (I SUMMARY DRilliNG OPERATIONS Pre-RiQ Work: 1. Set 20" conductor and weld an ASS Vetco landing ring for the ASS Vetco Multibowl Wellhead on the conductor. 2. Install 7' x 7' cellar and polyshield same. Ria 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 3245' MD /3225' TVD (+/-150' TVD below the top of the SV6 marker). POOH. 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 SOPE and test to 250/5000 psi. 6. MU 12-1/4" directional assembly 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 FIT to 12.5 ppg. (FIT/LOT procedure on file with AOGCC). 8. Drill 12-1/4" intermediate hole to casing point at approximately 10081' MD / 9469' TVD (into the Miluveach). Minimum mud weight of 9.6 ppg at the top of HRZ and 9.8 ppg at the top of Kuparuk. POOH. 9. Run 9-5/8", 47# intermediate casing. Cement the casing to +/- 4134' MD (top SV2 sand) in a single stage. Pack off the casing hanger. 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. MU 8-1/2" directional assembly and RIH to float collar. Pressure test the 9-5/8" casing to 3000 psi for 30 min. 11. Drill out remaining cement. Drill 20' of new formation below 9-5/8" shoe and perform a Leak Off Test. (FIT/LOT procedure on file with AOGCC). 12. Weight up to 11.3 ppg prior to drilling ahead. Drill the drilling liner hole to 11520' MD / 10784' TVD (top of Sag). POOH. 13. Run and cement a 7" 26# drilling liner. Set the liner hanger and liner top packer. Circulate off any excess cement. POOH with liner setting string. 14. RIH w/ 6-1/8" directional assembly and clean out to the landing collar. Pressure test the liner to a minimum of 500 psi over the leak off pressure established in Step 11 above. 't\ \'- 15. Drill out remaining cement. Drill 20' of new formation below ~ shoe with 11.3 ppg mud and perform a Formation Integrity test. (FIT/LOT procedure on file with AOGCC). Since the mud weight will be lowered to 9.3 ppg after the FIT, monitor the wellbore for 10 minutes. If no losses occur, displace with the 9.3 ppg drill-in fluid. 16. Drill 6-1/8" production interval to TD at approximately 12079' MD /11294' TVD. POOH. 17. RU Schlumberger E-line unit and run open logs (GR/Res/Den/Neu/Sonic;RFT). POOH and RD Schlumberger. 18. Make a clean out run, if required, and condition the hole for a liner. POOH. 19. Run and cement the 4-1/2" 12.6# 13Cr liner. Set the liner hanger and liner top packer. Circulate off any excess cement. POOH with liner setting tool. 20. RIH with 3-3/4" cleanout assembly. Clean out to PSTD. Pressure test to 3450 psi for 30 minutes with a 9.3 ppg fluid to confirm the system integrity. 21. Displace well to 8.5 ppg seawater and monitor. POOH. 22. Run the 4-1/2", 12.6#, 13Cr Yam Ace completion assembly to the top of the 4-1/2" liner at +/-11370' MD. Run a GLM at 3000' MD and a SSSV at 2000' MD. 23. Land the tubing hanger. 24. Nipple down the SOPE. Nipple up and test the tree to 5000 psi. 25. Displace annulus with inhibited seawater. 8 NS13 Permit to Drill ( ( 26. Set the packer. Pressure test the tubing and annulus to 4200 psi for 30 minutes. Shear the rupture disk in the GLM. FP with diesel to +/-1800'. U-tube diesel to tbg. side. 27. Install BPV. Rig down and move off. Post-Ria Work: 1. MIRU slickline. Pull the ball and rod / RHC profile from 'XN' nipple below the new production packer. 2. Pull the shear valve in the GLM and replace with a dummy valve. 3. Perforate interval based on PE recommendation. Estimated Spud Date: 5/20/01 Steve Chesher Operations Drilling Engineer 564-4196 9 NS13 Permit to Drill ( (' NS13 Riasite SUmmary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE ~ Gas hydrates may be present near the base of the permafrost. Mudloggers will be used continuously on NS13 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 NS10, NS27, NS29 or NS31. Mudloggers will be used continuously on NS13 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 with a higher mud weight (11.6 ppg). The intermediate casing is being set prior to weighting up the mud (for the Kingak). 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. ~ Bit balling on the NS29 was experienced in the Miluveach. The mud properties and PDC bit selection will be closely monitored to minimize potential balling. ~ The Kingak shale, in the offset wells, experienced severe hole instability. The casing shoe at the base of the Kuparuk, higher mud weight (11.3 ppg) and low angle (24.06 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. Severe lost returns were experienced on the NS29 in the Shublik and Ivishak. The LCM decision tree will be maintained on the rig. ~ Northstar is not a designated H2S pad. CONSULT THE NORTHSTAR PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 10 NS13 Schlumberuer Proposed Well Profile - Geodetic Report Report Date: Client: Field: Structure I Slot: Well: Borehole: UWI/API#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid NIE Y/x: Grid Convergence Angle: Grid Scale Factor: April 26, 2001 BPXA Northstar Northstar PF I NS13 NS13 NS13 50-029- NS13 (P6) / April 26, 2001 24.055° /3757.63 ft 14.9851 0.33~ NAD27 Alaska State Planes, Zone 04, US Feel N 70.49107762, W 148.6932927£ N 6030941.610 ftUS, E 659831.260 ftUS +1.23171236° 0.99992902 Survey I DLS 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 283.170° N 0.000 ft, E 0.000 ft KB 55.77 ft relative to MSL 15.670 ft relative to MSL 27.147° 57483.597 nT 80.899° April 14,2000 BGGM 2000 True North +27.14r Well Head ~- Station ID End Bid N 70.49107762 W 148.69329279 N 70.49107762 W 148.69329279 N 70.49107762 W 148.69329279 N 70.49107762 W 148.69329279 N 70.49107816 W 148.69329974 2500.00 3.00 283.17 2499.93 4.36 0.99 -4.25 2.00 6030942.51 659826.99 N 70.49108032 W 148.69332753 2600.00 5.50 283.17 2599.65 11.77 2.68 -11.46 2.50 6030944.04 659819.75 N 70.49108494 W 148.69338646 2700.00 8.00 283.17 2698.95 23.53 5.36 -22.91 2.50 6030946.48 659808.24 N 70.49109226 W 148.69348006 -- 2800.00 10.50 283.17 2797.64 39.60 9.02 -38.56 2.50 6030949.80 659792.52 N 70.49110226 W 148.69360798 2900.00 13.00 283.17 2895.53 59.96 13.66 -58.38 2.50 6030954.01 659772.60 N 70.49111493 W 148.69377000 3000.00 15.50 283.17 2992.45 84.57 19.27 -82.35 2.50 6030959.10 659748.52 N 70.49113026 W 148.69396593 3075.41 17.39 283.17 3064.77 105.92 24.13 -103.13 2.50 6030963.52 659727.64 N 70.49114353 W 148.69413579 3100.00 18.00 283.17 3088.20 113.39 25.84 -110.41 2.50 6030965.07 659720.33 N 70.49114821 W 148.69419530 3200.00 20.50 283.17 3182.60 146.36 33.35 -142.51 2.50 6030971.89 659688.08 N 70.49116872 W 148.69445769 3245.19 21.63 283.17 3224.77 162.60 37.05 -158.32 2.50 6030975.25 659672.19 N 70.49117883 W 148.69458693 KB Top Permafrost Base Permafrost KOP 1/100 Bid 2/100 Bid 2.5/100 SV6 NS 13 (P6) report.xls Page 1 of 2 5/2/01-2:01 PM Station ID I (ft) ~ (0) I (0) I (ft) I (ft) I (ft) ~ (ft) I (a/100ft) I (ftUS) I (ftUS) I I 13-3/8" Csg Pt 3245.20 21.63 283.17 3224.78 162.60 37.05 -158.33 0.00 6030975.25 659672.18 N 70.49117883 W 148.69458701 Bid 2.5/100 3345.19 21.63 283.17 3317.73 199.46 45.45 -194.22 0.00 6030982.87 659636.12 N 70.49120177 W 148.69488038 SV5 3371.11 22.28 283.17 3341.77 209.15 47.65 -203.65 2.50 6030984.87 659626.65 N 70.49120778 W 148.69495747 N 70.49121472 W 148.69504599 End Bid 3442.22 24.06 283.17 3407.14 237.12 54.03 -230.89 2.50 6030990.66 659599.28 N 70.49122521 W 148.69518013 SV4 3716.69 24.06 283.17 3657.77 349.00 79.52 -339.82 0.00 6031013.80 659489.83 N 70.49129483 W 148.69607056 SV2 4133.92 24.06 283.17 4038.77 519.08 118.27 -505.42 0.00 6031048.98 659323.45 N 70.49140067 W 148.69742424 SV1 4573.06 24.06 283.17 4439.77 698.08 159.06 -679.72 0.00 6031086.01 659148.33 N 70.49151206 W 148.69884905 TMBK 4961.82 24.06 283.17 4794.77 856.55 195.16 -834.02 0.00 6031118.78 658993.30 N 70.49161064 W 148.70011038 M87F 6692.10 24.06 283.17 6374.77 1561.84 355.86 -1520.76 0.00 6031264.67 658303.31 N 70.49204935 W 148.70572432 .- M60T 7349.16 24.06 283.17 6974.77 1829.67 416.89 -1781.55 0.00 6031320.08 658041.29 N 70.49221592 W 148.70785628 Top HRZ 9205.37 24.06 283.17 8669.77 2586.30 589.29 -2518.27 0.00 6031476.59 657301.09 N 70.49268631 W 148.71387916 Base HRZ 9282.03 24.06 283.17 8739.77 2617.55 596.41 -2548.70 0.00 6031483.06 657270.52 N 70.49270574 W 148.71412794 Top Kuparuk 9369.64 24.06 283.17 8819.77 2653.26 604.54 -2583.47 0.00 6031490.44 657235.58 N 70.49272791 W 148.71441220 Kuparuk C 9575.52 24.06 283.17 9007.77 2737.18 623.67 -2665.19 0.00 6031507.80 657153.47 N 70.49278009 W 148.71508031 Top Miluveach 9917.19 24.06 283.17 9319.77 2876.46 655.40 -2800.79 0.00 6031536.61 657017.23 N 70.49286664 W 148.71618891 9-5/8" Csg Pt 10081.46 24.06 283.17 9469.77 2943.41 670.66 -2865.99 0.00 6031550.46 656951.73 N 70.49290826 W 148.71672197 Top Kingak 10437.37 24.06 283.17 9794.77 3088.49 703.71 -3007.25 0.00 6031580.47 656809.80 N 70.49299840 W 148.71787686 Geo Tgt 1 10731.95 24.06 283.17 10063.77 3208.57 731.07 -3124.17 0.00 6031605.31 656692.33 N 70.49307301 W 148.71883277 Top Sag River 11487.57 24.06 283.17 10753.77 3516.58 801.25 -3424.08 0.00 6031669.02 656391.00 N 70.49326437 W 148.72128479 Target 11487.58 24.06 283.17 10753.77 3516.58 801.25 -3424.08 0.00 6031669.00 656391.00 N 70.49326437 W 148.72128479 7" Csg Pt 11520.43 24.06 283.17 10783.77 3529.97 804.30 -3437.12 0.00 6031671.79 656377.90 N 70.49327269 W 148.72139140 Top Shublik 11591.61 24.06 283.17 10848.77 3558.98 810.91 -3465.37 0.00 6031677.79 656349.51 N 70.49329071 W 148.72162237 Top Ivishak 11679.22 24.06 283.17 10928.77 3594.70 819.05 -3500.14 0.00 6031685.18 656314.58 N 70.49331290 W 148.72190665 Top Kavik 12035.13 24.06 283.17 11253.77 3739.77 852.11 -3641.40 0.00 6031715.19 656172.65 N 70.49340303 W 148.72306159 -. TO 14-1/2" Lnr Pt 12078.93 24.06 283.17 11293.77 3757.63 856.17 -3658.79 0.00 6031718.88 656155.18 N 70.49341410 W 148.72320377 Leaal Description: Surface: 1169 FSL 644 FEL 811 T13N R13E UM Target: 1969 FSL 4067 FEL S11 T13N R13E UM BHL: 2024 FSL 4302 FEL S11 T13N R13E UM Northina (Y) rftUSl 6030941.61 6031669.00 6031718.88 Eastina eX) rftUSl 659831.26 656391.00 656155.18 NS 13 (P6) report. xis Page 2 of 2 4/26/2001-7:38 PM - +-' Q) - Q)....J '+-W 8~ 0 0) C\I > II B c CO :;:¡¡: ........ ""- ..cf': +-'lO Q.lO 0)........ OCCl -~ CO .. U'+- .- 0) to:: 0) > > Q)Æ :::sW '- I- 0 2000 4000 6000 8000 10000 12000 Bid 2/100 2400 MD 2400 TVD 1':00. "283~'7. ä% 1'dèpàl1üre "" Bid 2.5/1002500 MD 2500 TVD . 3.döo 28;3.1'7.äz4döpartüie .. .... End Bid /13-3/8" Cog P6245 MD 3225!TVD ./ ../ 21.63i 283.17. az 163 departure' ::.> .'.' - .. .'~~~~~~~~~~137~5ä~~9:~:~:'~e .. .. ~:~'t: :¡(;'F(: MÖ ~\Ü(;~, ,YO .. . ...., .."j "..,. ...., n'" ..... ,n" .. ....~ "'" s'jl¡' :~:~:r1 rvïÖ ~\~~~ï:~ "rVD .. End B113442 MD 3407 TVD 24;06°'1283.170az 237 departure ":.: ""]"':".'."':"':.":':'."':'."": I I , IHold Angle 24.0610 I ¡ I I i . "I I .1 I ( (' Schlumberger "'ÿ~~!;'¡)\m'r;:'~ff,,~'::' 12Ó~~ ~,~u 1", '0~, 7\'}D . '''B~~.;:,'(;'f''~ir'in~1i'0~~ 'ï!~'~;5 r~1'D T£¡;~;'\l"',"[f'" (,\j.1. ~"? i'! t...1D :J,6:;6 TVO '" . i):j~{ '.1'Y:~'4' '~.Ú~Y ";Ù~.~.~:)' 'f!';-Ò' ",'.... i .. ,:~\)r ,¡~~f) tJ1T¡ 4;~'~(1 ,¡iVD .. I rt,1t~'¡\ ,~~'!f;~:"~~1D'(ï'l~~:¡"'fvcf '! ¡ i. .;.. . .. - - 9-5!8" Cog PI 10081 MD 9470 TVD ¡ '::,',., / 24.96° 283.17° az 2943 departure i : 2 '~j ;~ ;¡~F,~;~,~:il1~; /( ¡ .,/' 4000 6000 """""\":':'.'.""'I"".:>/,~;~~:,ï'.'~~~7~.~,,;~~4~~~¡;.üre'''.. j// ,// T'CogPI11520fl1D 10784TVD \::;/i ...._,...".. 24.06. 283.17° az 3530 departure .... ~~~o ..0" ...... ".10 .... .. TD /4-1/2" Ln. Pt 12079 MD 11294 TVD .".2.4_06.~....2.ß.3..17.~..az.... 3758 departure VERTICAL SECTION VIEW Client: BPXA Well: NS13 (P6) Field: Northstar Structure: Northstar PF Section At: 283_17 deg Date: April 26, 2001 KOP 111002300 MD 2300 TVD -' 0.00' 283.17. az 0 departure / 7 .... / . ¡... ............. .."...... //:.-/... Vertical Section Departure at 283.17 deg from (0.0, 0.0). (1 in = 2000 feet) ......,. ...¡. "'j" ti~~'7F: '(~Ï3t\ir\:1D"{L\'!~':""1"VÖ" . . . . . I tl.M;OT ~'~;~¡!9 MD 69'/!.' 'rVCi ..). I i I .:\: 9S~.rWR,~;;Q~¡>tr~.I~¡¡tQ^7Y.!~fJ . t ::::::::;:~':;:::~:" i i "T Tr:~ri'K!l1'¡:~;' K "~O,¡:~7'MJ)"'9 ï9'~ lV!? '''T'' I i i : :'f:'f¡!&:~\l~iii*';f;\~ð:'I~\i;f.\llEf¿,f¡~1~W?: "'j To'i'h"¡;',, 17(\';:;-11'10 "T12::'n'TVI:¡' "". ""I "1'. I -2000 0 2000 -3500 1500 TD /4-1/2" Lnr Pt 12079 MD 11294 TVD 24.06' 283.17' az 856 N 3659 W ^ ^ ^ I t- o::: 0 z 1000 -3000 r Cog Pt 11520 MD 10784 TVD 24.06" 283.17' az 804 N 3437 W ; ,I / / . , .~ . t;{ . / ~---~~ 500 I ¡ J Target! 11488 MD 10754 TVO 24.W 283.17. az 801 N 3424 W I t- ::::> 0 (j) V V V 0 -500 -3500 \ Geo Tgt 1 10732 MO 10084 TVD 24.06" 283.17. az 731 N 3124 W -3000 PLAN VIEW Client: Well: Field: BPXA NS13 (P6) Schlumberger Northstar Northstar PF 1 in = 500 ft 26-Apr-200l Structure: Scale: Date: -2500 -1500 -500 -1000 -2000 ..._........+.~......- { l\J).N: ¡d True North Mag Dee ( E 27.15° ) . 9-5I8~ C.~_Pt_- - 10081 MO¡ 9470 TVO ,24.06' 283.17' az . /671 N 28$6W End Bid /13.3/8" çsg Pß245 MD 3225 TVO 21.63. 283.17. ai 37 N 158 W -------- -- Bid 2.5/100 3345 MO 3318 TVD 21.63. 283.17' az 45 N 194 W End Bid 3442 MO 3407 TVD 24.06. 283.17. az 54 N 231 W Bid 2.5/1002500 MO 2500 TVD 3.00' 283.17' az 1 N 4 W ' Bid 2/1002400 MO 2400 TVO 1.00. 283.17. az 0 N 1 W KOP 1/100 2300 MO 2300 TVO 0.00. 28~.17. az 0 N 0 E - ----._-------__~___m- -2500 «< WEST -1000 -500 -2000 -1500 EAST »> 0 1500 - 1000 500 0 .-'" -500 0 ( BP Anticollision Report (" --- -,-~ -..- ""-'-- --- - - -"- - -.-.- -- -.---. ...,-,,-, ,..---..-.. -'- - --""'--"'---_.---"------'--~ --..-. --. ----- , Company: , Field: Reference Site: Reference Well: I Reference Wellpatb: BP Amoco Northstar Northstar PF NS13 Plan NS13 Date: 4/26/2001 Time: 19:45:06 Page: 1 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: NS13, True North N33E 55.8 -- --'--'----'-----'-'--"--'----- -- ..",--",,-------'-- - --'-- --- - ---~,-,---"_.._.,---_. ._"--,----- ~---~---"'----'-'-'--'-'--'-""------ - --"---~---,---,- - ---~---- ..- ...-- .__._-,-- -.-"-.-..---- :..:.:c.=:=:=---'.==-~===.===:=====-==--=-:::-:C:-:.=-::.~~~=~X~~~~=:::=;-, Reference: Principal Plan & PLANNED PROGRAM' Error Model: ISCWSA Ellipse Scan Method: Trav Cylinder North Error Surface: Ellipse + Casing , NO GLOBAL SCAN: Using user defined selection & scan criteria , Interpolation Method: MD Interval: 100.00 ft ¡ Depth Range: 40.20 to 12078.93 ft , Maximum Radius: 10000.00 ft - "---.,.-----,- -- ~- - " .. ,---, -'----'----'-- . -'-----,"-"------- ~ -" _n. - -. ---.-.,' - -. --'-- .. --- -.- - - --- - ---------_._~-- ~_. -,,-,,'---'-'------,,--_,~,__,,_- ..u_..,,- ._,,-,-~_._._-_. ------- --- --"---"".--'-~.._n .-. . --'-'-----'--- ---- --"-"-"'---."'--'- ----'-'--'~' -""-"------ --.--. ____h_______.___m- -. -- --.-...---. -- ---.. ------, I Survey Program for Definitive Well path I Date: 10/18/2000 Validated: No Version: 5 L:lan_~~~~m_L___~::~~~.__.._---- -_u.------ -_.__.._._-~o~:o~:_-------_.- --__~~O_I_~~:~- --- - .- I 40.20 1200.00 Planned: Plan #6 V1 GYD-GC-SS Gyrodata gyro single shots l___~_2~?~~~___1.~_~!8~~~_- -.. -~.~-~:~:~_1~~_#6 V.~--- -_._--_._-~--_._---~~-~.._-----_._._- -~~~- =_.~~~~_~r~____._.__.._. - . -.,--...--,.---. Casing Points ~t1~~!if:~~i~:H;~i-::~!~~~~~::::-:::=::~:-:::::~::=:~-~_n_] Summary _"-_h____"----_._-----,------,--,,-_O_--_.--_O"'_."~.._---,-,-,_o_----.......--._._._-_._,-,_._._--~O_--'_'___,"h'---_._._.o._o_~._---- '---'-.."-'-'--__-"_.0-.0"_____...---..- .- --.-"'---.-..-....- Reference Offset Ctr-Ctr No-Go Allowable MD MD Distance Area Deviation Warning ft ft ft ft ft ._-_..---_.._-_.._..._o~._o_._-_....._.__o_-_._._...,~.-"o_"'~.'._o_-'>_.__...__.._._._..-.._.__o_--~.__._......_--------~_..._--_._-_o_._..~_._._"..__.o__o_.---_...----"_O'--.-_~n.____.--,.'---_._--'-------_."._"_._---"'."--.".-'--->---..._-.-'.0- ,,,_._,-_.~~_.__..~...o_--_._,- Northstar PF NS10 NS10 V17 799.79 800.00 16.54 12.44 4.13 Pass: Major Risk Northstar PF NS26 NS26 V22 1399.94 1400.00 134.52 20.98 113.55 Pass: Major Risk Northstar PF NS27 NS27 V29 2678.23 2700.00 93.60 40.26 53.40 Pass: Major Risk Northstar PF NS29 NS29 V17 399.98 400.00 160.78 8.26 152.52 Pass: Major Risk Northstar PF NS31 Plan NS31 V5 Plan: Pia 1098.99 1100.00 181.51 20.75 160.77 Pass: Major Risk Seal Island SEAL-A-01 SEAL-A-01 V4 2906.29 2900.00 374.63 46.22 328.52 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02 VO 2810.15 2800.00 368.20 43.55 324.72 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02A V4 2809.92 2800.00 367.57 40.37 327.28 Pass: Major Risk Seal Island SEAL-A-03 SEAL-A-03 V4 2751.26 2800.00 278.26 48.41 229.87 Pass: Major Risk Seal Island SEAL-A-04 SEAL-A-04 V4 1605.66 1600.00 414.90 26.85 388.11 Pass: Major Risk <--------------- Offset Wellpath ----;.------~---> Site Well Wellpath --,._-_."._----._--_.,._-~.._._._._~-_.~---_.,----~_..O----'-'-_._----'------~--__O_>'h~'------~--._____h___'------._..__.hO_____-.--..--..'--.-.--.-_o..--..-..--.-,-",,--"'~--"_O__..'._--'~--"~--'-"--- .-.--.-.,--- Site: Northstar PF Well: NS10 Wellpath: NS10 V17 Rule Assigned: Inter-Site Error: Major Risk 0.00 ft --.----- --~-""",---,-_O_.O_-_.-.-"-""~---_._---"-'-"-----_._-- Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset. . TFO+AZI TFO-HS. Casing Distance. Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft .--'_~-~.'."_'>-----_,'o_--_,-'--~._.w_-,,-_._-_.~.._...__.._._-,_._...'._____'M..."_--'~O_-~---'_._'~"'..._~,--~_._.~-.._._..,..__._.._~._->--_._"-,._",_..~~---'_'.'__o_-_"_-"._..._--_.-_.__._._.~_.....~_.~---_o~-_.o~'-- 40.20 40.20 40.20 40.20 0.00 0.00 178.13 178.13 20.000 30.06 1.50 28.56 Pass 100.00 100.00 100.00 100.00 0.04 0.08 178.08 178.08 10.750 29.89 2.09 27.81 Pass 199.99 199.99 200.00 199.99 0.19 0.13 177.77 177.77 10.750 28.91 3.68 25.23 Pass 299.98 299.98 300.00 299.98 0.33 0.17 177.10 177.10 10.750 27.02 5.22 21.80 Pass 399.94 399.94 400.00 399.94 0.48 0.20 175.93 175.93 10.750 24.25 6.75 17.51 Pass 499.89 499.89 500.00 499.89 0.62 0.21 174.37 174.37 10.750 21.20 8.22 12.99 Pass 599.84 599.84 600.00 599.84 0.77 0.16 172.28 172.28 10.750 18.38 9.48 8.93 Pass 699.82 699.82 700.00 699.82 0.91 0.14 172.00 172.00 10.750 16.17 10.86 5.37 Pass 799.79 799.79 800.00 799.79 1.06 0.19 178.90 178.90 10.750 16.54 12.44 4.13 Pass 899.68 899.68 900.00 899.68 1.20 0.27 188.33 188.33 10.750 20.25 14.14 6.12 Pass 999.40 999.40 1000.00 999.40 1.35 0.39 195.57 195.57 10.750 26.96 15.92 11.09 Pass 1098.79 1098.79 1100.00 1098.79 1.49 0.54 199.76 199.76 10.750 37.74 17.78 20.11 Pass 1197.79 1197.79 1200.00 1197.79 1.56 0.70 201.72 201.72 10.750 51.71 19.49 32.53 Pass 1296.46 1296.46 1300.00 1296.46 1.57 0.88 203.08 203.08 10.750 67.91 21.04 47.39 Pass 1394.72 1394.72 1400.00 1394.72 1.59 1.08 204.06 204.06 10.750 86.39 22.66 64.53 Pass 1492.48 1492.48 1500.00 1492.48 1.61 1.27 203.71 203.71 10.750 107.40 24.28 84.24 Pass 1589.76 1589.76 1600.00 1589.76 1.64 1.50 202.82 202.82 10.750 130.48 26.02 105.97 Pass 1686.22 1686.22 1700.00 1686.22 1.68 1.76 202.58 202.58 10.750 156.81 27.89 130.88 Pass 1781.26 1781.26 1800.00 1781.26 1.72 2.07 202.88 202.88 10.750 187.88 29.90 160.50 Pass 1874.52 1874.52 1900.00 1874.52 1.76 2.44 203.26 203.26 10.750 223.91 32.07 195.09 Pass -------'---'---~-"'--------""----"'---"~-_.'.~ h_._.__--.,---".-.--..,--.,,---,----...-.-"---..-.. -,"_.,_.__.._.._-----_._--,-"...__..__._._-_..~-_.,-,. .__._.__.._-~_o._o..__..,-------- .. _"h_.__.--.--~.~.__.__.._h__'-- -------.....- Site: Northstar PF ( Drilling Target Conf.: 99% Centre Location: Map Northing: 6031609.00 ft Map Easting : 656692.00 ft Latitude: 70029'35.099N Shape: Circle ---~-_._._._._-----,---,-- - - .-- -- - §> ) :0C0 ~rr / ~C0 ~'\ / ----'-'-'---' '----'~'-"~'"'-,_. ~C0 ~(:) / s:JC0 /~~ S0C0 /13 ~C0 "'~ Target: NS 13 fit tgt '" (' ell: NSI3 dased on: Planned Program Vertical Depth: 10008.00 ft below Mean Sea Level Local +N/-S: 734.26 ft Local +E/-W: -3124.53 ft Longitude: 148°43'07.805W Radius: 250 ft 0à V <'0 V ~ V Óo V /0 G ( 5b V °0 U / --~ -_._-~-._-.- , Site: Northstar PF (. Drilling Target Con£.: 99% Centre Location: Map Northing: 6031669.00 ft Map Easting : 656391.00 ft Latitude: 70029'35.752N Shape: Circle -- -.- ----- -~-~----~-- ..-_...._------,---~--------_._-_._----- ~ ) ~C0 ~ / C0C0 ~ / S0C0 ~0) / ~C0 ~~ / C0C0 ~ "" / . --_...' -.-- '0-'--.---- SjC0 r'I~ Target: NSt3 SIt , , ~' ( ell: NS13 .:Sased on: Planned Program Vertical Depth: 10698.00 ft below Mean Sea Level Local +N/-S: 800.67 ft Local +E/-W: -3424.20 ft Longitude: 148°43'16.625W Radius: 250 ft Óo V $0 V // (; ( /0 2/0 >b V c90 V / ~ V TREE: ABB-VGI 5 1/8" 5ksi (. WELLHEAD: ABB-VGI 13-5/8" ( Multibowl5ksi 13 3/8", 68#/ft, L-80, BTC @ 3245' 4.5", 12.6#/ft, 13-Cr, Vam Ace TUBING 10: 3.958" CAPACITY: 0.01522 BBLlFT 9-5/8" 47# L-80 BTM-C @ 10081' 4.5" X NIPPLE, @ 11310" 3.813" 10 4.5" X NIPPLE, @ 11350' 3.813" 10 4.5" XN NIPPLE, @ 11360' 3.725" 10 4.5" WLEG, @ 11370' 3.958" 10 7", 26#/ft L-80, NSCC @ 11520' PBTO @ 11999' TO @ 12079' OATE REV. BY NS13 { '")RIGINAL KB. ELEV = 55.77' ( F. ELEV = 40.2' '.::B. ELEV = 15.57' SSSV @ 2000' MD wI HXO SVLN nipple - 3.813" 10 6.8PPG DIESEL FREEZE PROTECTION AT +1- 2000 4.5" GLM @ 3000' MD wi 3.833" 10 - 7" LINER TOP @ 9931' - 7" PACKER,13 Cr @ 11330' COMMENTS 4.5" LINER TOP @ 11370 4.5", 12.6#, 13Cr Vam Ace Northstar WELL:NS13 API NO: BP Exploration (Alaska) ..' .,1'" , .~>., ~/~ . - . ""'~\t~~~~~~1~~t!'l~11i1; H 188127 DATE 04/19/01 CHECK NO. 00188127 INVOICE I CREDIT MEMO GROSS VENDOR DISCOUNT DATE DESCRIPTION NET 041801 CK041801B PYMT OMMENTS: HANDL NG I N5T: 100.00 100.00 Per it to Drill ee 5tH - Terrie Hub Ie X4628 -rl5 \3 IE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ . . ';i~i~fL;;'", To ORDER Of ALÅ:, ..,.~.,..:.::';O. .:"', :::Jqri CONSERVATION COMMISSION 33~ WEST 7TH AVENUE SUITE 100 ANêHOiiAGJ= AK 99501 \2- ..:..:::.:.: ::.,'¡ .~(!;~<,<, -- ",.....:..'.. ..: ,"'- ._- III ~ 8 8 ~ 2 7 III I: 0 L. ~ 2 0 :} 8 g 5 I: 0 0 8 L. L. ~ g III ... ( ( TRANSMIT AL LETTER CHECK LIS1 CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANS NUT TAL LETTER WELL NAME ~~ \ ~ CHECK 1 STANDARD LETTER DEVELOPMENT V CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORATION ANNUL~,~, POSAL . NO INJECTION WELL ANNULAR DISPOSAL L.J YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name, on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has n,ot been requested. . . Annular Disposal, of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated... ANNULUS L.J YES + SPACING EXCEPTION Enclosed is the approved application for permit to drill tbe above referenced well. The permit is approved' 'subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (ComDanv Name) will assume the liability of any protest to the spacing exception that may occur. \)\~, <t-"f,.Cl.",,~~ 0"" ~~~"ò.~ I.. \:R\.~ ~O,'\..!è:.~ Ot-... \'{ ~~ l ~~ Templates are located m drive\jody\templates WELL PERMIT CHECKLIST COMPANY AP WELL NAME,IU.$' - /3 PROGRAM: exp - dev X- redrll- serv - well bore seg _ann. disposal para req - FIELD & POOL (qD I C> ð INIT CLASS C)~ .I -"-;>,, /' GEOl AREA ð ~ 0 UNIT# /1 ~C:: (j..., ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . N 2. lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available. in drilling unit.. . . . . . . . . . . Y N. 8. If deviated, is well bore plat induded.. . . . . . . . . . . ... . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can.be issued without administrative approval.. . . . . Y N 13. Can permit be approved before 15-day wait.. . . . . . . . . . N 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ~ N 15. Suñace casing protects all known USDWs. . . . . . . . . . . N 16. CMT vol adequate to circulate on conductor & suñ csg. . . . . N 17. CMT vol adequate to tie-in long string to suñ csg. . . . . . . . ~@ 18. CMT will cover all known productive horizons. . . . . .. . . . . N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . . N . " 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N ~~,~ ~\~ , ,",0 ~~~\Ù~ tç>.r\- 21. If a re-drill, has a 10-403 for abandonment been approved. . . -¥-N'" ~~ ..' .. ~ 22. Adequate well bore separation proposed.. . . . . . . . . . .. . N ~ \0 ~\(.. ~~~~ ~t'~""~ I \> \ù.~ ~ ...'"'I~ C" C\.J~'"" t- \~ 23. If diverter required, does it meet regulations. . . . . . . . . . N ~~\\.l;\Q\a\~«.~ ~ ~~~ '", J 24. Drilling .fluid program schematic & equip list adequate. . ~ . . N . 25. BOPEs, do they meet regulation. . . . . .¿-~Ä;---"'. . . . . N r 'i. h. C'h r-..r. . 26. BOPE press rating appropriate; testto "'.:)'J..J-..J psig. N t )\l-\~k~ \~~x--:::. L\\LJ'O ~\ 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N . ~~: ~~~~~~~:~:~=~~~U~d~n: : : : : : : : : : : @~ ~<.~~"'~~(J:\-~, \Z\~~,:>,<~,,\,~"-(~~~--,.~c..\~<,,\ ;~. 6:~~r:~~:~s~~ep~:'~I~r~~~g~~e:~~r~ez~~::ures. . ... Ã~ N ~ /7 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y.. /f ~J n . A R DATE 33: Seabed condition SUNey ~rf off-shore). . . . . . : : : : : : : N . $!æz6 / 34. Contact name/phone for weekly progress reports [exploratory on ~ Y N ANNULARDISPOSAL35. With proper cementing records, this plan . . Q.,\\~~« ~a ~~\~ ~\~~~~~\\ (A) will contain waste in a suitable receiving zone; . . . . . . . Y N (B) will not contaminate freshwater; or cause drilling waste. .. Y N to surface; . (C) will not impair mechanical integrity of the well used for disposal; Y N (0) 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: UIC/Annular COMMISSION: ~þ~ WM C r APPR _~1E ~ ENGINEERING ~'~E GEOLOGY APPR DATE c 0 Z 0 -t :E :::0 ,r '\ -t m Z -t J: en )- :xJ m > ( Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ') -) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. SCANNED NOV 1 B 2004 ) ) ) ) ) ) ) ') ) ) ) 1 ) ) ) ) ") ) ) ) ) ) ) ) ) ) ) ) ) ) ) ) ,) ) ) ) ) » ) ) ) ) , I~ CONFIDENTIAL ScIIIIInI8Pger BP Alaska Northstar PVT Study Wells: NS-09, NS-13, NS-08 and NS-15 Surface Separator Samples ),ùh2t"t J Áò/-aÕ>~, Àó;1. -(::,'>'// ; ).úÄ-oS-y ~+"f(\ ~ itr F;k BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, AK 99519-6616 U.S.A. A Report for: By: File#: Date: Oilphase - OBR Schlumberger 9419 - 20 Avenue Edmonton, Alberta T6N 1 E5 Canada (780) 463-8638 www.dbrgroup.com 20023132 May 25,2004 SCANNED NOV 1 8 2004 ) ) ) ) ) ) , ) ) ) ) -) ) ) ) ) .. "'.. .' . . - .. "" . . , . .. . OILPHASE - CBR "~ .,.,. , ",,' '. ' ,~IJ" ~1¡tY,'.,~s~uranc"e",.., Pr.,'oc, ,e, s~ '.' ," ',' ,"" " ,.. "", ",""'" ,,' '", ,','. ,",','. " "'"....,~ Oilphase-DBR has a continuing commitment to provide the highest quality fluid property data and service to all its clients. The Company's philosophy is that all property measurements and calculations be performed to a level of accuracy and repeatability that is unsurpassed in the industry. This objective is achieved by continually improving and developing new state of the art measurement techniques and equipment. The key to maintaining this ability is a rigorous program of quality control and suitable management systems to maintain them. In particular. it is a requirement that all laboratory measurements be performed by qualified engineering technologists and be supervised by an experienced Research Engineer/Scientist at a Ph.D. or M.Sc. level. Open lines of communication are maintained so that qualified staff at all levels can provide input. The results of all the work are interpreted and reported by a Researcher supervising the project. Finally. following the completion of each report, an independent review is made by senior technical staff to confirm the technical consistency and readability of the report. All property measurements and calculation procedures for a particular study are maintained in the company Archives for a period of 3 years. These notes are available for review by clients if requested. All measurements are made following the most appropriate procedures for obtaining accurate and repeatable data. All measurement instruments are calibrated periodically as required. to maintain accuracy. Rigorous quality assurance programs are in place to insure and maintain the accuracy of our analytic procedures. Details of these calibrations are also available at the clients' request. ) ) ) ) ) ) ) ) ) ) ) ) ) ) ) ) ) ) ) ) ,) ) Effective December 8. 1999. after meeting the International Organization for Standardization (ISO) quality assurance standards, Quality Certification Bureau Inc. has granted the Oilphase-DBR registration of our Quality Management System to the requirements of ISO 9001 :1994. To achieve ISO certification. Oilphase-DBR underwent an extensive and lengthy training and review process of operational procedures that culminated with the required third-party quality audits performed by Quality Certification Bureau Inc (QCB). Oilphase-DBR's certification was granted by aCB upon the successful completion of the audits. The ISO 9001 certification further strengthens Oilphase-DBR's position of industry leadership. ) The company has a stated philosophy that shortcuts in accuracy or technically appropriate procedures are not acceptable under any circumstances. The staff continuously strives to develop and maintain superior experimental procedures and quality control. Reference information indicated below provides traceability to the raw data related to this project. To answer any 'Questions, clients are requested to contact the Project Manager indicated below. Oilphase-DBR File No: 20023132 Oilphase-DBR Notebooks: 6/2001 & Trentl/2001 1. Laboratory Procedures for This study 2. Data Correlation and Reporting A>:;I A~~ ./-- i - c.ß Craig Borman ~r . Lab Supervisor " .,.~.~ Jinglin Gao, M.Sc. (Ch. E. Project Manager 3. Report Reviewing I (t~-+ Moin Muhammad. M.Eng. Manager - Research And Fluid Analysis Services 1 " -.~...u<_...,-~._-- ) .~ Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 0 Oilphase-DBR ) ,-......... .---..... 0"""'"''''''-'''--''''' ... ....-.". "........ .--- ....... ..... "...-- ...... --... ..--................-.. .. ......._-".._.._....---,,~.._---_..--..--_........ ...... .." '.. ...... '''''.''...''..".''..' -"."....-...-......-...." ""'--m.___.--- EXECUTIVE SUMMARY -.,,----.... ... " ".....--.. ....-. .....-.......... ... -.."....---.-----. .. .. "". .._.... ...--'.'---'-..''''-'-'''..''''_..0.'''_'- Field: Wells: Sample Depth: Reservoir: location: Northstar NS-09, NS-13, NS-08 & NS-15 Surface Separator Samples Ivishak Alaska Oilphase-OBR completed a series of PVT studies for BP Exploration (Alaska) Inc. on recombined reservoir fluids collected from NS-13, NS-09, NS-08 and NS-15 wells in its Northstar field. The major results are summarized below: Pressure: Temperature: Estimated - 5175 psia 254.5 of GOR STO API By single stage ambient flash: 2304 SCF/STB By OL test @ Tres: 2515 SCF/STB By 5-stage separator test: 2049 SCF ISTB Single-phase viscosity at Psat & Tres: 0.131 cp 39.6 39.2 41.7 FVF 2.360 2.537 2.218 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 1 Oilphase-DBR --..,.....--,. . ...o.... .-.-. .,."., .., ''''~n"__-.._.._...... .....--."......".-.... -'... ..,,-~. ............. """',,","'-..__._--n...,....," ....,....- .-.-.""'"'...., ,o... ",. -".--o....-.----..,.-.---.-..-."., . . .,-- .. "",",...,-""------,........" ",.." ..,. ,.. "... TABLE OF CONTENTS QUALITY ASSURANCE PROCESS.................... ................ .......................... ......... ...................0 EXECUTIVE SUMMARY.................... .................................. ........................................... ...........1 1.0 INTRODUCTION...... ........................................... .................................... ..... ........................6 2.0 SCOPE OF WORK. ............... ................... ......... ........ ............. ..... ................ ......................... 7 2.1 Sample Preparation and Analysis ............................................................................. 7 2.2 Sample Recombination.............................................................................................. 7 2.3 Phase Behavior Analysis.......................................................................................... 8 2.4 Oead Oil Wax Test & Formation Water Analysis........................................................8 2.5 I nterfacial Tension Measurement............................................................................... 8 3.0 FLUID PREPARATION & COMPOSITIONAL ANALYSIS .................................................8 3.1 Compositional Analysis............................................................................................. 8 3.2 Reservoir Fluid Recombination and Analysis............................................................ 9 3.3 Oead Oil Wax Test & Formation Water Analysis ......................................................9 3.4 I nterfacial Tension Measurement........................................................................... 1 0 4.0 PHASE BEHAVIOR MEASUREMENT ..............................................................................11 4.1 NS-09, NS-08 and NS-15 Reservoir Fluid Partial PVT Measurement ....................11 4.2 NS09/NS-13 Reservoir Fluid Full PVT Study.... ..... ...... ..... .......... ........ ...... ............ ..12 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 2 Oilphase-DBR TABLES Table 3.1: C30+ Composition of NS-13 Separator Oil TC-1137 .................................................16 Table 3.2: C30+ Composition of NS-13 Separator Oil TC-1119 .................................................17 Table 3.3: C30+ Composition of NS-09 Separator Oil TC-1136 .................................................18 Table 3.4: C30+ Composition of NS-09 Separator Oil TC-1120 .................................................19 Table 3.5: C30+ Composition of NS-08 Separator Oil TC-1126 .................................................21 Table 3.6: C30+ Composition of NS-08 Separator Oil TC-1142 .................................................22 Table 3.7: C30+ Composition of NS-15 Separator Oil TC-1124 .................................................23 Table 3.8: C30+ Composition of NS-15 Separator Oil TC-1141 .................................................24 Table 3.9: C15+ Composition of NS-09 & NS-13 Separator Gases ...........................................26 Table 3.10: C15+ Composition of NS-08 & NS-15 Separator Gases .........................................27 Table 3.11: C30+ Composition of Recombined 5100psia Psat NS-09 Oil .................................28 Table 3.12: C30+ Composition of Recombined 4850 psia Psat Oil ......................................... ..29 Table 3.13: C30+ Composition of Recombined NS=-08 Oil .........................................................30 Table 3.14: C30+ Composition of Recombined NS-15 Oil .........................................................31 Table 3.15: C30+ Composition of Recombined 5100 psia Psat NS-13 Oil ................................32 Table 4.1: CCE of Recombined 5100 psia Psat NS-09 Oil @ 254.5°F .....................................35 Table 4.2: CCE of Recombined NS-08 Oil @ 254.5°F .............................................................37 Table 4.3: CCE of Recombined NS-15 Oil @ 254.5C>F .............................................................39 Table 4.4: Separator Test of Recombined 5100 psia Psat NS-09 Oil ......................................41 Table 4.5: Compositions of Produced Gas by Separator Test on 5100 psia Psat NS-09 Oil ...42 Table 4.6: CCE of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F.......................44 Table 4.7: OL of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F - Liquid Phase Properties.... ....... ................... .............. ............. .... ......... .................. . ........... .........46 Table 4.8: OL of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F - Vapor Phase Properties...................... .......... ..... .... ......... . .......... .. .............. . ... .. .... . ..... ... . ......... ..50 Table 4.9: Viscosity of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F ...............52 Table 4.10: Compositions of Produced Vapor by DL Test on 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F ........................................................................................ .52 Table 4.11: Separator Test of Recombined 4850 psia Psat NS-09 + NS-13 Oil ......................54 Table 4.12: Compositions of Produced Vapor by Separator Test on 4850 psia Psat N S-09 + N S-13 Oil . . . . . . . . . . .. . . .. . . . . .. . . .. . . .. . . . . . .. .. . . . . .. . . . .. . . . . .. .. . . . .. . . . . . . . .. . .. . . . . . . .. . .. .. . .. . .55 Table 4.13: Separator Corrected GaR & FVF .........................................................................57 Table 4.14: Summary of PVT Test on 4850psia Psat NS-09 + NS-13 Oil ..............................59 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 3 Oilphase-DBR FIGURES Figure 3.1: C30+ Composition Comparison - NS-09 & NS-13 Samples ...................................20 Figure 3.2: C30+ Composition Comparison - NS-08 & NS-15 Samples ...................................25 Figure 3.3: LP Separator Water Composition ........ ..................... .......... ....................... .............32 Figure 3.4: HP Separator Water Composition ........ ..... ............... ..... ....... ............... ........ ...... .....33 Figure 4.1: CCE of Recombined 5100 psia Psat NS-09 Oil @ 254.5°F....................................36 Figure 4.2: CCE of Recombined NS-08 Oil @ 254.5°F ............................................................38 Figure 4.3: CCE of Recombined NS-15 Oil @ 254.5°F ............................................................40 Figure 4.4: CCE of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F .....................45 Figure 4.5: OL of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F - GaR as Functions of Pressure ........................................................................................4 7 Figure 4.6: OL of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F - Liquid Phase Properties as Functions of Pressure........................ ......................................... .48 Figure 4.7: OL of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F - Vapor Phase Properties as Functions of Pressure....... .......................................................... ..49 Figure 4.8: Viscosity of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F ..............51 Figure 4.9: Separator Corrected GaR & FVF ....... ...... .......... ..... ...... ................. ............. ...... ....58 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 4 Oilphase-DBR APPENDICES Appendix A: Summary of Oilphase-DBR Capabilities........................................................ A1 A.1 Fluid Preparation of Compositional Analysis..................................................................... A 1 A.2 Techniques & Apparatus................................................................................................... A 1 A.2.1 PVT Cell.................................................................................................................... A 1 A.2.2 ODSR Solids Detection System................................................................................ A2 A.2.3 OOBR High Pressure Microscope (HPM) ................................................................ A2 A.2.4 OOBR Particle Size Analysis (PSA) ......................................................................... A3 A.2.5 Cambridge Electromagnetic Viscometer (EMV)........................................................ A4 A.2.6 Capillary Viscometer (CV)......................................................................................... A5 A.3 Procedures........................................................................................................................ A6 A.3.1 Constant Composition Expansion (CCE) ................... .............................................. A6 A.3.2 Oifferential Liberation (OL) .... .................................................. .... ............................. A7 A.3.3 Constant Volume Oepletion (CVO)........................................................................... A7 A.3.4 Multi-Stage Separator.............................................................................................. A7 A.3.5 Viscosity Measurement Using EMV ......................................................................... A7 A.3.6 Oiscrete Isothermal Oe-Pressurization.............. ....... ..... ..... ...................................... A8 A.3.7 Isobaric & Isothermal Titration............ ........................... ........................................... A9 A.3.8 Isobaric Temperature Sweep (Live Oil Cloud Point) .............................................. A12 A.4 Live Oil Bulk Filtration ..... .................................................. ................ ........... ............... .... A 13 A.5 Oead Oil Pour Point........................................................ ............................................... A 13 A.6 Live Oil Pour Point......................................................................................................... A 14 A.7 Model Pipeline Test for Gel Strength ............................................................................. A14 A.8 Wax Appearance Temperature by Cross Polar Microscopy.......................................... A16 A.9 Core Flooding Apparatus.............................................................................................. A 17 A.10 Asphaltene Content by Modified Syncrude Method..................................................... A 18 A.11 SARA Analysis .. ..................... ....................................................... .......... ..................... A 18 Appendix B: Determination of Oil/Brine Interfacial Tension ............................................. 81 ( ( Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 5 Oilphase-DBR -.." .., ".. .. - "... .... '" .. .__.._,--,,----_..-,. -.".".,.." ...", --...-..."..... ,"'.. , ...... . .. . ~ " ,,--..---....... _--m._._..."--..,,..........--'."'" ,., .."... .,-'''-_U'--'''.. . BP ALASKA NORTHSTAR PVT STUDY -..-..-.-.,..".-.-.. ,.., ._,_....._~",--"",....... ."..,--,..,,,., ",...-...............-, ..... "._"..." .,.....", "".,.....""......". -.....,..,.",,,-,._,,,,.,",, . '''.-.-.. .....- ...-"............--..-- ...,...,,,,,... "'''_'''--''n..... Field: Wells: Sample Depth: Reservoir: Location: Northstar NS-09, NS-13, NS-08 & NS-15 Surface Separator Samples Ivishak Alaska 1I81w¡{.]lll(~ BP Exploration (Alaska) Inc. was interested in conducting a series of PVT studies on recombined reservoir fluids collected in its Northstar field located in Alaska. Oilphase-OBR, Edmonton, Canada was commissioned to perform the experiment. A scope of work is summarized in Section 2. Oilphase-OBR received the first batch of separator oil and gas samples in February 2002, which consisted of samples from NS-09 and NS-13 wells. In May, 2002, the second batch of samples consisting of separator oil and gas from wells NS-08 and NS-15 arrived. These separator samples were used to reconstitute a series of reservoir fluid. A complete inventory of samples received at Oilphase-OBR, Edmonton is summarized below in a tabular form: Summary of Separator Samples Sample Cylinder Well Fluid Description Sample Separator Receiving Number Designation Volume Conditions Date Psig¡OF 1 st batch Feb., 2002 TC 1138 NS-09 Separator Oil 800cc 725/125 Feb., 2002 TC 1120 NS-09 Separator Oil 800cc 725/125 Feb., 2002 TC 1136 NS-09 Separator Oil 800cc 725/125 Feb., 2002 MM33085 NS-09 Separator Gas 20liter 725/125 Feb., 2002 MM38865 NS-09 Separator Gas 20liter 725/125 Feb., 2002 MM33082 NS-09 Separator Gas 20liter 725/125 Feb., 2002 TC 1119 NS-13 Separator Oil 800cc 740/128 Feb., 2002 TC 1137 NS-13 Separator Oil 800cc 740/128 Feb., 2002 MM38810 NS-13 Separator Gas 201 iter 740/128 Feb., 2002 MM33040 NS-13 Separator Gas 201 iter 740/128 April,2002 LP separator water 1 liter April, 2002 HP separator water 1 liter 2nd batch May, 2002 TC 1126 NS-08 Separator Oil 800cc 711/1 08 May, 2002 TC 1142 NS-08 Separator Oil 800cc 710/105 Oilphase-DBR FILE #: 20023132 Oilphase-DBR BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 6 May, 2002 0342 NS-08 Separator Gas 20 liters 711/108 May, 2002 0327 NS-08 Separator Gas 20 liters 710/105 May, 2002 TC 1141 NS-15 Separator Oil 800cc 700.7/92 May, 2002 TC 1124 NS-15 Separator Oil 800cc 700.4/94 May, 2002 0329 NS-15 Separator Gas 800cc 700.7/92 May, 2002 0343 NS-15 Separator Gas 800cc 700.4/94 ~'i'I.]::~¡~ 2~:1 . .; "SàmÞ~'~ftrepåråtiöft}&::Aî.1a'ySls a) Sample conditioning and restoration by heating, pressurizing and mixing. b) Separator gas analysis to C15+. c) Separator oil analysis to C30+ includes GaR and density. d) Oead oil molecular weight by freezing point depression. 2~'2:;:.....:J,'Såm~~'RëÇòñtti~tít')... ( C ( ( ( ( l r ( , ( ( ( ( ( ( ( ( ( ( ( ( a) Reservoir fluid #1 - NS-09 reservoir fluid with saturation pressure of 5100 psia at Tres: Recombine -2 liters of reservoir fluid # 1 to a specified saturation pressure of 5100 psi a at Tres (254.5°F) using NS-09 separator oil and gas samples. b) Reservoir fluid #2 - NS-09 and NS-13 mixture with saturation pressure of 4850 psi a at Tres: Add NS-13 separator oil into about 1 liter of the recombined reservoir fluid #1 (NS- 09 reservoir fluid) to have recombined reservoir fluid #3 with a saturation pressure of 4850 psia at Tres of 254.5 of. c) Reservoir fluid #3 - NS-08 reservoir fluid with GaR of 1602scf/sep. bbl: Recombine -1 liter of reservoir fluid # 6 to a separator GOR of 1602 scf/sep. bbl using NS-08 separator oil TC 1142 and gas 0327. d) Reservoir fluid #4 - NS-15 reservoir fluid with GaR of 1441scf/sep. bbl: Recombine -1 liter of reservoir fluid # 7 to a separator GaR of 1441 scf/sep. bbl using NS-15 separator oil TC 1124 and gas 0343. e) Reservoir fluid #5 - NS-13 reservoir fluid with saturation pressure of 5100 psia at Tres: Recombine -2 liters of reservoir fluid #2 to a specified saturation pressure of 5100 psia at Tres (254.5°F ) using NS-13 separator oil and gas samples. f) Compositional analysis of the above recombined reservoir fluids #1 to #5 to C30+ 2.3, .' :PhasØB~h.viorArtalysis On recombined fluid #1, which is the NS-9 reservoir fluid with saturation pressure of 5100 psia at Tres (254.5 OF): a) Perform a Constant Composition Expansion (CCE) test at Tres. b) Perform a 5-stage separator test. c) Measure single-phase viscosity at Tres at two different pressures. Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 7 Oilphase-DBR On recombined fluid #2, which is a NS-9 and NS-13 mixture that has a saturation pressure of 4850 psia at Tres (254.5 OF): d) Perform a Constant Composition Expansion (CCE) test at Tres. e) Perform a 6-step Differential Liberation (OL) test at Tres, including oil viscosity at each step. f) Perform a 5-stage separator test. g) Measure single-phase viscosity at Tres at two different pressures. On recombined fluid #3 and #4, which are the NS-08 and NS-15 reservoir fluids: h) Perform Constant Composition Expansion (CCE) Tests at Tres. 2'~4f",:::;~;","bj.d¡.Ð",Wã]Ç..T.st,'iÎndFôi1tatïön::watil'<Ät1.rys¡'s a) Measure Wax Appearance Temperature 0NAT) of NS-09, NS-13, NS-08 and NS-15 dead oils using Cross Polar Microscopy (CPM). b) Wax content of dead oils using UOP 46-64 method. c) Compositional analysis of formation water samples. d) Prepare -200cc of dead oil from NS-13 separator samples and send to US Geological Survey in Denver, USA. 2~,5,. . ,'.-..CiaITenslon',,...uremént a) Prepare and send 25cc of NS-13 dead oil and 50cc of recombined fluid #5 to the Petroleum Recovery Institute (PRI) in Calgary for interfacial tension measurement. b) Measure the interfacial tension (I FT) of the NS-13 dead oil with the formation water collected from the high-pressure separator at 200psia and 122°F. c) Measure the interfacial tension (1FT) of the recombined fluid #5 (NS-13 reservoir fluid with a saturation pressure of 5100psia at Tres) with the formation water collected from the high-pressure separator, at 5175 psia and Tres (254.5°F). After receiving the separator oil and gas samples in the laboratory, the first batch of samples was conditioned at 176°F and the second batch was conditioned at 122°F. The oil samples were allowed to gently and continuously rock for over 48 hours while maintaining the pressure at -1000 psi. The gas samples were hand-rocked occasionally. During conditioning, oil samples TC1138 and TC1126 were lost due to an unexpected release of the safety valve on the sample cylinders. 3.1 CQmpositional Analysis The procedure is described in the fluid preparation and analysis section in Appendix A. The compositional results for the separator fluids are presented in Tables 3.1 to 3.8 and are compared in Figures 3.1 and 3.2 respectively for the first and second batches of samples. Oilphase-DBR FILE #: 20023132 Oilphase-DBR BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 8 ( (' r c ( ( ( ( ( ( ( ( ( [ ( ( ( ( ( ( ( ( ( , ( ( These Tables include the measured and/or calculated molecular weight, and the compositions of the vapor and the liquid generated from the flash for each sample, and also contain the calculated properties of the C7+, C12+ and C30+ fractions including mole 0/0, weight 0/0, molecular weight, specific gravity and boiling point. Separator gas samples were analyzed to C15+. The results are presented in Tables 3.9 and 3.10 respectively for the first and second batches of samples. . ~Q$ervôir:,Fìuld';:~écOíriþ'íi~tion:an~Mal~.lš Reservoir Fluid #1: NS-09 reservoir fluid with saturation pressure of 5100 psia at Tres (254.5°F). Separator gas from well NS-09 was recombined with the separator oil from the same well in such a way that the recombined fluid had a saturation pressure of 5100 psia at reservoir temperature of 254.5°F. This was achieved by adding a certain amount of gas and oil into a recombination cylinder. This cylinder was equipped with a mixing ring and placed inside a forced air circulation, thermostated oven. After addition of the gas and oil, a sub-sample was charged into a PVT cell where a pressure-volume relation test was performed to determine the saturation pressure. If the saturation pressure was higher than the specified pressure, more liquid was added. If the saturation pressure was lower than the specified pressure, more gas was added. This process was repeated until the measured saturation pressure was within an acceptable range of the specified value. The analyzed C30+ compositional data of this recombined fluid are presented in Table 3.11. Reservoir Fluid #2: This fluid was obtained by adding NS-13 separator oil into the recombined reservoir fluid #1 (NS-09 reservoir fluid). The resulting mixture had a saturation pressure of 4850 psia at Tres (254.5°F). The C30+ compositional data of this recombined fluid are presented in Table 3.12. Reservoir Fluid #3: NS-08 reservoir fluid. Separator oil and gas samples from well NS-08 were recombined to a separator GaR of 1602 scf/sep bbl. This corresponds to the producing GaR at the time of sampling (gas rate at standard conditions: 7.848 mmscfd; oil rate at separator c~nditions: 4898 bblld). The C30+ compositional data of this recombined fluid are presented in Table 3.13. Reservoir Fluid #4: NS-15 reservoir fluid. Separator oil and gas samples from well NS-15 were recombined to a separator GaR of 1441 scf/sep bbl. This corresponds to the producing GaR at the time of sampling (gas rate at standard conditions: 8.179 mmscfd; oil rate at separator conditions: 5674 bblld). The C30+ compositional data of this recombined fluid are presented in Table 3.14. Reservoir Fluid #5: NS-13 reservoir fluid with saturation pressure of 5100 psia at Tres (254.5°F). The NS-13 separator oil and gas samples were recombined into reservoir fluid that had a saturation pressure of 5100 psia at Tres (254.5°F). The C30+ compositional data of this recombined fluid are presented in Table 3.15. Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 9 Oilphase-DBR 3.3 - Dead .OUWaxTest and Formation Water AnalysIS Wax Appearance Temperature (WAT): Cross Polar Microscopy (CPM) was used to measure the wax appearance temperature (W A T) of the dead oil resulting from flashing the separator oil at 176 of to ambient conditions. The sample is taken hot at 140°F and then cooled at a rate of 2°F/min to 32°F while the CPM photomicrograph is being recorded. The results are reported below: NS-09 dead oil W AT NS-13 dead oil WAT NS-08 dead oil W A T NS-15 dead oil WAT 89.0 OF 92.1 of 96.0 of 92.7 of Wax Content: Wax content of NS-09 and NS-13 dead oils was analyzed by Maxxam Analytical Inc., Edmonton, Alberta using UOP-46-64 standard method. Briefly, this method involves dissolving about 2 grams of sample in petroleum naphtha. The solution is clarified using fuller's earth. The petroleum naphtha is evaporated and the clarified oil redissolved in an acetone-petroleum naphtha mixture. This solution is then chilled to 0 OF and filtered through a cold filter funnel, the wax being collected on an asbestos mat in the funnel. The wax is then washed from the mat into a weighing flask, using hot petroleum naphtha. The naphtha is evaporated and the wax weighed. Probably because of sample mishandling (temperature was lower than the wax appearance temperature while sampling or transfer), the analyzed results were lower than expected: NS-09 dead oil wax content NS-13 dead oil wax content 0.26 wt% 0.16 wt% After discussions with Mr. Terry Wilcox of BP Exploration (Alaska) Inc., another sample was taken by flashing NS-13 recombined reservoir fluid (recombined fluid #2) at 176 of and sent to Maxxam. The sample was heated to 104 of for 10 minutes prior to sub-sampling for wax content analysis. The wax content of this sample was analyzed to be 3.36 wt%. I NS-13 dead oil wax content, 2nd analysis 3.36 wt% Wax content of NS-08 and NS-15 dead oils was analyzed by Norwest Labs, Edmonton, Alberta using the same method. The samples were heated to 104 of for 10 minutes prior to sub-sampling for wax content analysis. The results are reported in the table below. NS-08 dead oil wax content NS-15 dead oil wax content 3.9 wt% 3.7 wt°/o Formation Water Analysis: Compositional analysis of formation waters collected at low- pressure separator (LP separator) and high-pressure separator (HP separator) was also performed by Maxxam Analytical Inc. The results are presented in Figures 3.3 and 3.4. Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 10 Oilphase-DBR 3~4 'l"t~~çi~I.T..g~IQ...(IE~)FM,êlšllréJTIjl1t After review the compositional data of the water samples, Mr. Terry Wilcox of BP Exploration (Alaska) Inc. decided to use the high-pressure separator (HP separator) water to conduct the interfacial tension (1FT) measurement. The measurement was performed by the Petroleum Recovery Institute of the Alberta Research Council in Calgary, Alberta using a pendant drop method. Both dead and live oils with formation water systems were measured. The dead oil was flashed from the NS-13 separator fluid, and the live oil was the NS-13 reservoir fluid with a saturation pressure of 5100 psia at Tres (recombined fluid #5). The 1FT of dead .oil and formation water was measured at 122°F and 200psig in order to keep the system above the wax appearance temperature; while the live oil and formation water system was measured at Tres (254.5°F) and 5175 pisa. The results are presented below in the tabular form. A detailed report on 1FT measurement may be found in Appendix B. 1FT of NS-13 STO & formation water @ 214 psia &122°F 16.0 dyne/cm 1FT of NS-13 live oil & formation water @ 5175 psia & 254.5°F 25.9 dyne/cm .~~'J::~:h'd::l~1S The phase behavior measurements were performed using the techniques & procedures described in the fluid phase behavior measurement section in Appendix A. 421' .' ."""~~$;~.~-(J,~¡¡"(j:'''~~~:$,';~,~~îigJ'~;,'f,lþløcf'ÎJ1i.1,'IJ':~~:'Mø.$9~e1'Ö~",1 CCE Test: A Constant Composition Expansion (CCE) test was performed on the recombined reservoir fluid #1 (NS-09 samples recombined to a saturation pressure of 5100 psia at Tres), #3 (NS-08 samples recombined to the producing GaR of 1602 scf/sep bbl), and #4 (NS-15 recombined to the producing GaR of 1441 scf/ sep bbl). The results are presented in Tables 4.1 to 4.3 and are plotted in Figures 4.1 to 4.3. The bubble point pressures were determined from the volumetric data and were also visually confirmed using a high magnification cathetometer. ( Psat of NS-09 Reservoir Fluid @ 254.5°F Psat of NS-08 Reservoir Fluid @ 254.5°F Psat of NS-15 Reservoir Fluid @ 254.5°F 5095 :t 15 psia 4885 :t 15 psia 4640 :t 15 psia l ( These tables also contain the measured/calculated liquid densities and compressibility values in the single-phase region. The pressure relative-volume data in the single-phase region was curve fitted using the ITableCurve" software package (Windows based; developed by Jandel Scientific). The selected functions and the V-function values are provided in the table; the compressibility values were calculated using the derivative of the selected function. Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 11 Oilphase-DBR Live Oil Viscosity: The viscosity of recombined reservoir fluid #1 (NS-09 samples recombined to a saturation pressure of 5100 psia at Tres) was measured using an electromagnetic viscometer (Cambridge) at reservoir temperature. The results are reported in the table below. Live fluid viscosity @ 5500 psia and 254.5°F Live fluid viscosity @ 5200 psia and 254.5°F 0.106 cp 0.097 cp Separator Test: A 5-stage separator test was performed on recombined reservoir fluid #1 (NS-09 samples recombined to a saturation pressure of 5100 psia at Tres). The results are presented in Tables 4.4 and 4.5. Table 4.4 provides the equilibrium vapor and liquid phase densities, the individual GaR and formation volume factor values for each stage. Additionally, this table contains a summary of the cumulative GaR and residual oil properties for the complete separator test. Presented in Table 4.5 are the compositional data of produced vapor at each stage and the residual oil. The separator conditions are provided below in a tabular form. Pressure - psia Temperature - of Stage 1 750 160 Stage 2 Stage 3 Stage 4 Stage 5 325 70 20 15 157 157 157 60 4i~,.....i;......t.f$~9JH$~1,~.~@.§~()lr.....J;ll.Jld>f\l.II,:'P¥t;$~~(lY A full PVT study was performed on the recombined reservoir fluid #2, which was NS-09 and NS-13 mixture with a saturation pressure of 4850psia at Tres. CCE: The CCE test results are presented in Table 4.6 and plotted in Figure 4.4. The bubble point pressure was determined from the volumetric data and was also visually confirmed using a high magnification cathetometer. I Psat of NS-09+NS-13 Reservoir Fluid @ 254.5°F I 4855 :!: 15 psia I Differential Liberation (DL) Test: A 6-step Oifferential Liberation (OL) test was conducted at reservoir temperature (254.5°F) from the bubble point pressure to 1500psia. After completion of the last step, the equilibrium liquid phase at 1500 psia was flashed to ambient pressure at room temperature. As such, a total of 7 steps of the DL test were performed with the last step being conducted at room temperature. The data from differential liberation test are supplied in Tables 4.7 and 4.8. Table 4.7 provides the cumulative liberated and solution GaR, calculated liquid phase density, formation volume factor (FVF), and liquid viscosity values at each pressure step. The GaR data is also presented in Figure 4.5. The GaR was calculated by taking the total gas phase mass generated at each pressure step and converting it to a standard condition gas volume using the ideal gas law. The liquid density, FVF, and viscosity data are also presented in Figure 4.6. The liquid density at the bubble point pressure was previously determined from the CCE test and was used to initiate the calculations. The liquid density at each pressure step was calculated by mass Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 12 Oilphase-DBR balance. The viscosity of liquid at each step was measured using the Cambridge in-line viscometer. These data along with the single-phase viscosity of the original reservoir fluid are also presented in Table 4.9 and Figure 4.8. Presented in Table 4.8 are the measured equilibrium vapor phase properties at each step. As expected the vapor density decreases with decreasing pressure. Figure 4.7 shows the vapor density, gravity and deviation factor (compressibility) dependence with pressure. The compositional data of produced vapor at each step and the residual oil are presented in Table 4.10. Separator Test: A 5-stage separator test data are summarized in Tables 4.11 and 4.12. Table 4.11 provides the equilibrium vapor and liquid phase densities, the individual GaR and formation volume factor values for each stage. Additionally, this table contains a summary of the cumulative GaR and residual oil properties for the complete separator test. Presented in Table 4.12 are the compositional data of produced vapor at each stage and the residual oil. The separator conditions are provided below in a tabular form. Pressure - psia Temperature - of Stage 1 750 160 Stage 2 Stage 3 Stage 4 Stage 5 325 70 20 15 157 157 157 60 ( C ( l ( l ( ( ( ( ( ( C ( ( " ( [ t ( ( t Reservoir Fluid Properties From Differential Liberation Test & Separator Data: As stated in the raahe Properties of Petroleum Fluids" (McCain, 1990), the underlying assumption in generating reservoir fluid properties from a PVT study is that at pressures below the bubble point, the process in the reservoir can be simulated by differential liberation, while the process from the bottom of the well to the stock tank can be simulated by the separator test. Based on this assumption, fluid properties at pressures below saturation can be calculated by combining the data from the differential liberation and a separator test. The measured and the adjusted solution gas GaR and formation volume factor data are shown in Tables 4.13. In each case, the fluid properties at a particular pressure step were calculated by drawing on the differential liberation flash at reservoir temperature followed by the change in fluid properties as that reservoir oil is produced through the separator train to the stock tank. However, at pressures above the bubble point, solution GaR is constant, while the FVF is reduced due to oil compressibility. Shown in Figure 4.9 are the separator corrected GaR and FVF data as the liberated reservoir oil is produced at the surface. PVT Study Summary and Discussion: Table 4.14 contains summary information for the experimental study comparing GaRs, formation volume factor and residual liquid properties from each of the three flashing procedures in the study. These include: . the single stage flash of the reservoir fluid in the GaR apparatus at room temperature. Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 13 Oilphase-DBR . the differential liberation of the reservoir fluid at reservoir temperature. . the separator tests. Usually, an increased number of flashes at a fixed temperature down to atmospheric pressure results in a decreased total volume of evolved gas. That is, if an oil is flashed down over multiple stages, it is expected that the overall GaR and FVF should be lower than if the same oil was flashed in a single stage process at the same temperature. This behavior is important to consider when comparing the three different flashes in this study; however, it is equally important to recognize that the single stage GaR flash, differential liberation and separator test were completed at different temperatures which also has an effect on the resulting properties. As can be seen in Table 4.14, the OL flash has the highest GaR due to the relatively high temperature used for this test. Similarly, the FVF from the DL is also the highest and the corresponding residual liquid is the heaviest. Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 14 Oilphase-DBR TABLES & FIGURES ( [ ( Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 15 Oilphase-DBR Gas Liquid Overall Group Component MW Mole % Wt % Wt % Mole % Mole % g~¡i'); ;' ii,,' {' , ' i!i):"'\P," J,' t"','%~íØ1; ;,\\;81;1 &\'\Kì;:;;0¡\íì6~¡;4';$';¡{~~*0il1¡¡'!~è"tT;i4'§i¡Ø1~li; ¡¡¡Mil;; . :\,@*i¡:¥';1¡0'i$~¡~{i,¥.;;%;,~¡¡;¡4*%{~~\;«i;~~~('Jj(;~ì;ì¡;í;;ità; ;{:S; ""'è,~~2ø:¡i!;*;;î\ ii,; ,~~ H2S 34.08 0,00 0.00 0,00 0,00 0,00 ''''~t,<'I<'H " . ". ::'2:ä;øjs~::'!;~;;!;';';~,;;/;:;Ai~~ä2:::>'}i:'jf.::t}Géi~œ;" '''''':;'{,liìó.fi}ì,i';i;:iiJ. '.'£;T~pi~ti:0!;;~i";::UP}.t/:i~?Q;ff\i¡WrF! C1 16,04 44,02 0,00 1,94 14,39 14,39 ç~¿; ;;> , >"". ,/y;;,';~(}?:,~V/';':}; t,:;{.~;~$,:~;;;}ì;.;;'::.: ; ~~;~::::Q}oøiiftt(;';1 ;A\/.~;i/:f,2Q:;';'}i';;';tÚ,i:t~}'tl~Qij.F§:&,::;' ::¡;:<";Z,~+ØØàh::~::,.; C3 44.10 17.00 0,45 2,46 6.65 6,65 j~'> ".,;:::'>:;;>,$1:2:<;;;',:::; ':'3;42f':j~!:~\:'i """" ;~'();~j.: : ,',:', : ',i:):f2t4~;Y;;,' ,', ji;:t4:h; ,:~,~. N-C4 58,12 7,33 1,29 2,34 4.79 4.79 ~~t~é ,: ,,' ':;" ':f'if,h!'~2tj¡~t~J2;t~l¡;;:;'fr~2<','~)~Z{\;'!7.A'i~\) :;!'~:\J;;D~t~f~':¿¡\:~\iibf ;z!t"i1"i¡,z1~@Ft'f¥;¡;~;rIAJ:t;#fi~í?J[~~jJ;~f::r1W:t?;]~;!~K1§,,~"~{;"1Si N-CS 72,15 1.88 1,60 1.82 3,01 3.01 C6 86~ 1.04 3;34 3-28, 4.53, MCYC-CS 84.16 0,16 0.86 0.82 1.16 IEÑ:fëîír"""'''' '.«"."""7if1T "(5."06""'-'<O"""'-"Õ:22, "', "Õ.21 . "Õ:32" CYCL-C6 84,16 0,16 1.18 1,11 1,61 Ç7 ' 100.20 0'.28 3:87 3:60 ' 4.28 MCYCL-C6 98,19 0,12 2,59 2.39 2,90 r(jLQÉ"'~ " ,9~fiif>."', ,,', ,,"(103: '," ,~~to~à:r ,i(ti,4",:' :"Ó;9§", C8 114,23 0.09 5.22 4,78 4,98 ~~¡;:'t .: ,;'~F1œ5t7:: ')';(f;;;;"ti~,,':c,. <)'>:, .',::0;31')'/'.';, <~;~:::f~:2ik:;,';;t;H,'\><':.+j(}¡3;1i!"~,,;."< M&P-XYLENE 106.17 0,01 0,80 0.73 0,82 ~po:t.£ijE?;~;~> ;" ,'.' , ',I.. ,; ,,' ,iq6~:1i',;.' -"".' ::3~'~:,;{;q;1~Ò;~;; : ;,;" " è: ': ,:' . ';':ø;~. :,,' ': ,,.' :;, i <;b:45, ::, ",:';¡'~;:f:ô#5j~e~ii<:~: ;':~':;F:,~;~,:;;:: ::: ':" i: C9 128,30 0.03 4,66 4,25 3.94 18.71 °'°" 134.0()\" "'O'.ôj'<",,':S:82: :~,~9 " 4:.71' C11 147.00 0.00 4,78 4,35 3,53 C12 161.00 0.00 4.333.94 2.91 C13 175,00 0,00 4,88 4,44 3,03 Çf~", '('.Í,èþ:øo. 'i," ;;0';00': " '4;4~, .4:(}2";; .. ,', " ,'2~7;if:,: C15 206.00 0.00 4,27 3,88 2,25 C'¡,6'~', .:':,'ì22:ötf;", ,',q:Qn't:'. 3:7;Ì('" '-' ":;3:~; ::;1~f'::,' ,;., C17 237,00 0.00 3,47 3,16 1,59 Ç'fiH. :"".,; ';':!,' ::~Y?~!?1,:~/;;~/:' ";;~<..:;9i.Q<í';">~: ';:;)~(tk§~\W:.\:::;j;!~", ',:~:20J.; , , :;;:;;;:''1t~':' ,', "",,0./\:::: "" C19 263,00 0,00 3,36 3,06 1,39 þ20 ' tl$:qO ,'O:()o, ' 2:1'5 ':':::?,;~ 1;08:, C21 291,00 0.00 2.59 2.36 0,97 <:22, "~iQO:" ",' :();OO::J'¿,' ", ',2)36 . ," c '2;;15, <, ';;Ó;&ifi C23 318,00 0,00 2,25 2,05 0.77 Ç24'~3'!AW, j,:L:Ó,OOi" "2,O!$<, ,:': ':1:.8,7',' "":;,',Q¡;$-1/ C2S 345,00 0.00 1,87 1,70 0,59 (;$ 3~.Oó,' ;O;oO~~¿' " ,t7~ ,:1,62 ' a~54 C27 374,00 0,00 1,74 1,58 0.50 ~':3,ä8~O(p ;(lOO - ~1C~7; > 1:52, ,OA7, C29 402,00 0.00 1,59 1.45 0,43 (;30+,' .'. ,,'5åÖ.Oò' , :0.00 :1:73, ,;,:iØ3 , ,;1~44' ~ji~~~W;(g¡~I)" " .." ,\ 16S~O " ,>" " Calculate~ MW (g!mol) 33,0 161,0 119,2 $,ingíè~J:lashGO~@STD ,5Èt2 (M:t1M3), ',315: API Gravity 41,8 AvèiàgeGasGntVltY., '1;139', COlmn:riiqatióh(wt%)*, Dead Oil Bâsis Contamination Corrected GOR COrítàmihätion'Correct8dAPI' Table 3.1 BP Alaska Northstar Separator Fluid Well: NS-13; Cylinder TC1137 C30+ Composition 7,62 8,56 6,85 (SÇF./BBL) (SC~/BBL) Group C7+ C12+ C30+ Compositional Data for Different Groupings Mole % Wt% MW 52,3 81.8 186.4 25,3 54.9 258.3 1.44 7.0' 580.0 SG 0.84 0,88 1.03 . Estimated with the Skimming Method. (Gozalpour F" Danesh A" Tehrani A. -H., Todd A. C., Tohidi 8., SPE Technical Paper # 56747, 1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C, H" Fluid Phase Equilibria, 16, 137-150 (1984)) Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 16 B.P. (OF).* 462 611 981 Oilphase-DBR Table 3.2 BP Alaska Northstar Separator Fluid Well: NS-13; Cylinder TC1119 C30+ Composition Gas Liquid Overall Group Component MW Mole % Wt % Wt % Mole % Mole % .çQ~. ._, .._:.':~",-" ..,:.., __,,-,:.ÆMU;':~;,.:,~,l.~_,::;~::.JM~g,:;:;,:~~,~ -,:.;~~k::'!)J)iLi~~~.; :_:,~~iTXqJlØ";;:~'i.~~:~2~;3;~1'.'L:;:t, /~ci:.:~M:;~~.~~r,,~ H2S 34.08 0.00 0.00 0,00 0.00 0,00 ~2.: . ,,. ." : ,28.Q1',-, " ::c:' :Q.~, :~~':~:~;9D-_:.,,;:::,: .~';;Ô,o§\~~:;~r',J~::Hi~;;,;_:'~:,;, ,,:d~;~(~ '.~ C1 16,04 43.09 0.00 1,91 14.20 14.20 ~~< ,: ,',: ',:., " ,'. -,~:~~:.." . ,\~::~' ""~::~:~;''-':;:'~I: '~.:~)::"~~¡r'~~\'>§;:":;':'~;1~~~i:' - ':':::f-': ~ : t~'.;'..:.' ': i~;::tf.:::"'.: ~'f~¡~ ;:: .:'. -'<,;Q~$J.;;,'..'é ".t";.~O;MU:;.':;~;/':: ,f{~,t~.;:~\""::':,,,':-':1$~'. N-C458.12 7,63 1,20 2,31 4,76 4.76 J~~,~~..~:",;:,-:_'~;<-,",-;:.:.c.~,_~l~.1~t:¡;~:~, ..:~,.:;;L1~_~':::~:~: ,2::.:;:::::9~~:;,;l,:..2;';~&L;:~t~~~:~tQL:f:;:.2~~?{12~,~:~'.' ':.:::'?jg.:,:,.:" N-C5 72.15 2.10 1.51 1,79 2.96 2,96 MCYC-C5 84.16 0,19 0,83 0,80 1.14 ( ( ( ( ( r ( f '- ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( f:¡. C22 C23 C24 C25 C26 C27 359.00 374.00 111~;1~¡.t~'\'¡~\\\~1~~$1 ì%ý~~.'\R'}_\\~¡~1 ;¡fI~¡¡~\.i~fJ,ffj~~'~I¡'t~ ~'ii'_'IfI?l'\1.$~~ .1~\'.t~I_1I_~._.œ IÆ\'?BI~"l"\11 C29 402.00 0.00 1,48 1.35 0.40 6,76 Calculated MW (g/mol) 33.5 161.9 119.6 §~g9j~,,:~~g!:~'~~b;.§Q~@'§m::(~~{;E:. ;;;,;;::'.!~7~q.::<~~ .' .':.,;: : .",::,/tM~~~},:,,:,:Ú ::;::i~Jj;~i;:;;k<,::f:~;;;;~<i~i9i~;:.;:k~r::;;,.;)j;:':':<:;:f,i~~~t::;E::($ÞÈt~.~Ii~f~; API Gravity 42,0 ~;~~:~t~:':~J;i "~:';:I',;:;,,:,::'r:,'-:~,:,;';i '~ãd"~~:$iS;")::: ::';';'!5'~': Contamination Corrected GOR Cont.mlijation'CQiTØCt8d'AÞi,,:/::;' . .,;,,:.:;:(~~E!~~~i. Group C7+ C12+ " C3o... Compositional Data for Different Groupings Mole % Wt% MW 52.6 82,0 186.2 25.4 258,1 'Hso . ",580;0. SG 0.83 0.87 , ,/, 1;03',<.:, B.P. (OF)"" 461 610 .981 . Estimated with the Skimming Method. (Gozalpour F" Danesh A., Tehrani A, -H" Todd A, C" Tohidi 6., SPE Technical Paper # 56747, 1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C, H" Fluid Phase Equilibria, 16, 137-150 (1984)) Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 17 Oilphase-DBR Table 3.3 BP Alaska Northstar Separator Fluid Well: NS-09; Cylinder TC1136 C30+ Composition Gas Liquid Component MW Mole % Wt % CO2. , 44.01 ,.,i 6.73 .0;00 H2S 34,08 0,00 0,00 Ni.' -28.01 . ë~25 .' 'Q~OO . C1 16,04 42,21 0,00 C2 30.07 .15.60 . : 0.00 ' C3 44,10 17.23 0.45 1-C4 .58.12 .3.55 . , 0.32 N-C4 58,12 7.82 1,23 t-C5:, ' '72.15 1;99'. ,,1,02 N-C5 72.15 2,18 1.55 ,C6' .' 86.20 1;26 a:33 'MCYC-C5 84,16 0,20 0.86 øaaENE 78.11 ' '0;07 0.22 CYCL-C6 84,16 0,20 1.19 C7 100;20 0.34 '.~.97 MCYCL-C6 98,19 0,15 2,60 I TOLUENE 92.14-- 0:04 0.82 C8 114,23 0,11 5,35 C2~ØENZENE 100;17 0.00 '0.31 M&P-XYLENE 106,17 0,01 0,84 a-XYLENE 106.17 0.00 0.50 C9 128.30 0.03 4,77 ;c10 134.00 0.01 '5.93, C11 147,00 0,00 4,87 9~:2> ., ' ", - ',- :~'~>,;~;1~@';i~':V:'Y , .: ;,J\;'~i;Q;po):t,t ::'; .: j';:;,'}~~-~ø:~~\':0:?": C13 175,00 0,00 4,93 t1~;' , .j '.' "1~:pq;"/;',;":::.:::':j'p'¡~:~'~i:';;:":'~''';-:FW4i~::j::/( , C15 206.00 0,00 4,28 ê16t~ '.- / 7,,:;:;i~~~::,<' ;:;,~:i~~iQ{öÞHi;"}~"J~----:,:j:~:;'::~;1Ø'(:';:''iY , C17' " 237,00 0.00 3.46 ,p,lr., " :'~~~j,~ø,Q'~,>::,' :.: ',;'P;ÓP:g'Yi':: c,~ '::3;4 f,::ó::;, C19 263,00 0,00 3.32 !J2ó,: , '::?t5,~QP,: " . , ,:, ;:O~ØQ\¡\" ; '.¡~2~1~; C21 291,00 0,00 2,54 ~~,;' .. , ,,"'~:~¡ijij', ,".,: 'q~!8LQ~ØØ~i~'" .. ,; - ",,:i2~~:?Y¡;::ó C23 318.00 0.00 2,21 CU'.:' ' ',ä3f:oo, 0;00, His'" . C25 345,00 0,00 1,91 C2ti::>:~;øo'>:';::;',i,":p:(;)(r ", ',;., , " if}63';;~ ; C27 374,00 0,00 1,68 Çi, ' < '- ';,~'ït.øø ' -<(J+(j~i,~<;~i}/",,;{;j;~:, C29 402,00 0,00 1,51 Q30+', , ,,'- ;'". , ,58(ÙjÔ~:';<O.ÔO';,':'" '; ;/(;13. : lII~s~~:.,(.gI~()Jr :,: è', 'j,;:o'.;;",~!ý~/:--c''-:~;, :1~¡0 ,,-, -, Calculated MW (g/mol) 33.9 160.5 Single Stage Flash GOR @ STD 60.3' (M3/M3) API Gravity 41,8 Avéràge Gas Gravity 1.172 Contamination (wt %)" Dead Oil Basis Contamination Corrected GOR iContamination Corrected API (SCF/BBL) Wt% ,0.85 0,00 '0;02', 1,95 ""'1.3'5 2,60 0;$ , 2.42 .1,33 . 1,86 3.31 0,82 022 1.12 . 3~68 2,39 0;75 4,87 . 0.28 0,76 0.45 4,31 6.35 4,40 Y~':;":~:,;i~i~1." 4.45 '. ';;:!;4fpf'~ 3.86 ',}:W$~';l!{;i!';W" 3,12 , ~,,;:;{,,:<?4$;; . 2,99 '\,'i;;:2;~;\(" " 2,29 '~;,Y/;2;~" ' 1,99 1~19' . 1,72 , j'~Y1;4t>:/; 1,51 ;(yj;;1;~:, ,; 1,36 ,::L'6~9i',¡ Overall Mole % 228 0.00 -';0;09 14,31 S,2S1 6,93 1.79 , 4,90 2.-17 3,02 4:52 1.15 '0.33 1,61 4.32 2,86 .0.96 5,01 0.31 0.84 0.50 3.95 , 4.70 3.52 '" ; :;;::::;~:~;mt;5;r:;!:l";}~j{'~}\~;'t4.:,t~\.:;> 2,99 '.f':'îi4~tlf"?:;c;.: ", ';'/IØ:~?:,,:,' 2,20 , ~;;':;i{?'~1!,t~{':q:~1:;¡:';;: 1,55 .,",,:,, ,~~¡::j~,~:~:;~/~)~:J'-'~-~:~,-:~~<:.'~-, 1.34 ..' ;:n\1i:(j!i":, ,.,,' 0,93 ",,0;&'1'>: 0,74 .'q.$'. 0.59 ';",0:.48,', ' 0,48 /:(),~ " 0.40 "'~,,:,:,,,-,~,_;.,,;4,1' , , ~;'~~':':{~~[~ ,,' :~:'}.,~~>~ - " "~:~~. ~.~~~ ':~~.>,~"5t¡~;~~;;~i~i~~!~~~:;~:\" ~ Group Compositional Data for Different Groupings Mole % Wt% MW Group Mole "10 2.28 ' 0,00 .à09 14.31 '5:29 ' 6.93 1.79 4,90 ~11 3,02 7,60 117,6 339 Live Oil Basis SG C12+ "C30+ 54.0 7,0 24.7 , 1,41 257,4 580,0 0,88 1.03 . Estimated with the Skimming Method, (Gozalpour F" Danesh A" Tehrani A, -H., Todd A, C., Tohidi 8., SPE Technical Paper # 56747, 1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C H., Fluid Phase Equilibria, 16, 137-150 (1984») Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 18 18,76 8.34 (SCF/BBL) B.P. (OF)- 458 609 981 Oilphase-DBR Table 3.4 BP Alaska Northstar Separator Fluid Well: NS-9; Cylinder TC1120 C30+ Composition ( l [ ( ( r t [ r ( ( ( l , ( ( ( ( (, ( Group C7+ C12+ C30+ Compositional Data for Different Groupings Mole % Wt % MW 51.0 81;0 185~2 24.3 53,8 258,0 1044 1;1 580.0 SG 0.83 0,87 1.03 B.P. (OF)** 459 610 . 981 . Estimated with the Skimming Method, (Gozalpour F" Danesh A" Tehrani A, -H" Todd A, C" Tohidi 8., SPE Technical Paper # 56747, 1999) ... Boiling Points Calculated using the Twu Correlation, (Twu, C, H" Fluid Phase Equilibria, 16, 137-150 (1984» Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 19 Oilphase-DBR Figure 3.1 BP Alaska North Star Separator Fluid Well: NS-13 & NS-09; Cylinders TC-1137, TC-1119, TC 1136, TC 1120 C30+ Composition Comparison 1 00. oo~==uu_~-~=u=--=-=~~ -- - -. -- -uu u_u=--.~~u.u~=~====~~=--::::.. --:. :~:~~: ~~:: ~;.=~:~===~-=~==~ - -~--_u_----- ------______m--~____-----______n____- - NS-09, TC 1136 ~------ ----- - ---- - - -----0 _..~- -- --~--..._.~---- -----_.-._-~-- - ---------- -4- NS-09, TC 1120 10.00 --.: ... C CÞ (.) ... CÞ Q. ... .s::. C) '¡; 3= 1 . 00 ~I 0.10 --.: ~ 0.01 . . . , , L . . . , . . . , , . . .. .. . , . , . . . . . . . . . . 6''' .fJ-'" ~" v' v'" v" ,¡1' .¡J /1' ~ð> ð' C?" .<,t'" çP ð çP ~'" ð' ¿'" ~'" ~'" v'" eJ<> v" v'''' v," v~ v'" v"" v~ v"" v'''' r!f ()' &' ()" r:t dJ v~ ¿p ét ét r::f ~d ~.r (l' ",,,,& "rß'<t) , ..-9~ cY-f!-~ ¿; ~'IY Components Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-OB, NS-15 Separator Samples Oilphase-DBR 20 Table 3.5 BP Alaska Northstar Separator Fluid Well: NS-08; Cylinder TC 1126 C30+ Composition (SCF/BBL) " Group C7+ C12+ C30+ Compositional Data for Different Groupings Mole % Wt% MW 50;8 81.0 186.5> 24,0 53,8 262.2 1,79 8.9 580.0 SG 0,83 0.87 1.03 B.P. (OF).. 462 618 981 I' . Estimated with the Skimming Method, (Gozalpour F" Danesh A" Tehrani A, -H., Todd A, C" Tohidi 8., SPE Technical Paper # 56747, 1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C. H" Fluid Phase Equilibria, 16, 137-150 (1984)) Qilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 21 Qilphase-DBR Table 3.6 BP Alaska Northstar Separator Fluid Well: NS-08; Cylinder TC1142 C30+ Composition Gas Liquid Overall Component MW Mole % Wt % Wt % Mole % ='~:;'~'>:' 'h ,o, ~>"':';~:g~}/" ,; "~v-";:"¡~:~~' ,<,i,':" 'g~~~r: ',' <~~~" :-::~:~- ~~~5;'/':J1{~!';,i ",,/, ,,: ¡'¡\'X¡~~:~:~~' ',;"/l'~~:~';":Zt~~f" ""~~i:-:'::'''\;::=i::':¡':'~~: :;;~":{'~~~~"'" ç~i;fS\ìi" ' :;:', ' ",~;;;':Îjj~Ø~/' ;;:'çi}~Ùtlt~~Á#(Êii~:t¡;>,;~qo;;'t ,,~:;:~?:'ih~l'~;~i'/S"" ':;!}~i!'(S-~1.§':; ~2,~::: -; , C3 44,10 17.98 0,31 2,71 7,10 ~';" :';5J:'1,?:;'i~ ".-" ',~':"" ,", 'H)~,;c, ",.Q.- : ' '/1~tl., N-C4 58.12 7.68 1.09 2.35 4.67 ~ij}i}i~¿?F ': ,,"};/~;~öJ'($3,?ii:.;';; ~\2-!(::'iF~~~:~;;:r ::--/':";> '. 1rø~:SE);;,'L:,:';<:'Cj~~t~;.';.:';h jc:;~.tt~. "'. " N-C5 72,15 1.95 1,58 1,85 2.97 ~:¡tii;i~;":;~~é ' '\/~ 'i:).',:;:\;"~2~&'.;t~,,~¥~,,~;;;<:'Í~W.:,:: ",:: ,:E~.;i~#;,:L~: ,:,-" ;/i,3:~:: .,::';¡>"~$~';;j,';'.. " MCYC-C5 84.16 0.17 0.88 0,84 1.15 B.~~ ,;/'~,î~f1'f, :';i(;;ó:öä ' '<J~~r 'O:2~, "o;~ ' CYCL-C6 84,16 0.17 1,21 1.13 1.59 !"Wãt~~;; >'" ,>~,;~~~~'i;;::';;'~~é(it;<~~'i;:7,':'i;;;¡,;,?,:';.:ji~~!~X;i,," 'c,.' "1¡~:' ::~I"'='-'1~~J¿;~&i:';,f, ,<'i:",:,; : tØ\:Uê8.. ,'~¡14' ~::' :~,; ,:~' :' " ;~~QJ':' O:~"~' 'g~~;', ,- .~~ÓÓ' C8 114.23 0.10 5.44 4.91 4.97 ~~: ":'i:''iØài''7f/(' ;",>",':-:;:q:øø:" ,-";-t<ij~lf:;," 'C>(fnr",.,tMt, M&P-XYLENE 106.17 0.01 0.86 0,78 0.85 ff~. ,,,, "~0&17 .., 000, ',::O:,S,",',9,',J;,y; , ,;" ,'0.5.3,:,'" ''-;,',.:,..,;.~,~;Q...::,.,$8,'<,.,','"" .: :', > ~. :c;"::"ëè,<;~''''';{.:} ~~:,':'::':':~E'~~'T':,:(::, ..E;H~~~',~d:'~' :., "',:"c:,:c(õ;.~:)}. 4.95' . 4,45 4:01 . 18:7i ' 01.':;'. ,)r~Oò," 0.018:05' 5~43 , 4:69 C11 147.00 0.00 4,94 4,43 3.49 01,21" ,>" . ç',;;~j't61föq:i, ,'<'i' ,'ô:Qo' ',<,' '4;~>1 :;.>. "3~.: ,',- ::':';.21ä6~' C13 175.00 0,00 4.90 4,39 2.90 .ç~. "', <", :t9.b:ÒÒ . , 'O.po, '. 4:52 4;9f!., . ",~~1,'o .' C15 206,00 0.00 4.23 3.79 2.13 ~~'}::,;¡;;:¡:;::, . ::'~::':i:i:\~~:\:::':;_;;'0~~)ì¡-:"'~~:\::;b?;;:,(: .,,::::.\~~~/ ::)'f1:'::~2":' :':(:f:~~~~: ,I, .~::" ." ." . öÇ1~<': .:.~i25~:Öð:' -'g~Ò9";3,~:"': 3;04' '':<;'J~,' ,,' C19 263.00 0,00 3.13 2,80 1,23 C20 27ß;ÔO, '0.00' 2.:67' , 2.~ ;tA>.t C21 291.00 0.00 2.44 2,18 0.87 .(;22' '. . ';~:Oo- Ö:aò 2.20 . 1:970.75 C23 318,00 0,00 2,10 1,88 0.68 ~~tœ: ~ . ,;O.t»': '. 1.88:: . 1;68 'Q;$ C25 345,00 0,00 1.80 1,61 0,54 <:28 359:00 0.00 1.52 1.36 ' 0:44 C27 374~00 0,00 1,62 1,45 0,45 Ç_,;i.~oó ,t;j.~'. ' "1:44' 1:29 '0,39 C29 402.00 0,00 1.45 1.30 0,37 ë_¿~.~. ,:'" ,,'580;OOd ',0:00 " ,8;547.65 1,53, .~,~~.IY)"~':HL' ';;'~::""''';'''.' c,i,,;.:;',::,'~~'l::::, Calc~lated MW (SJ/mol) 33.8 ~,I.~~~;fE~b~QRO$TD ~,~ API Gravity 42.3 ~==:~)~:'" ".. ," ,\OÞdci~:S1$ Contamination Corrected GOR ~ôi1t8ïhJnâtïoil.cort8ctêd'API 160,8 ,(",,~IM~), ' 3~7 Group Mole % ":_")2)1.8:",: ' 0,00 ')';;0;:10:," 14,72 ;,::;'Ji~I~~::'~", ',~ 7,10 "', .fctr 4.67 , ,;;~;~1r ,; .,:! 2,97 , ' " , 7.60 '.16.4,1" ,_. -, 7,96 ,(Sqf/f)BL), (SCF/BBL) Group C7+ Compositional Data for Different Groupings Mole "10 Wt% MW 50.8 . ~.8 184,2 23,8 258.3 ,5ØO.Q ,--,. . ..~. , SG 0.83 0,87 1.03 . Estimated with the Skimming Method, (Gozalpour F" Danesh A" Tehrani A, -H" Todd A, C" Tohidi B" SPE Technical Paper # 56747, 1999) - Boiling Points Calculated using the Twu Correlation, (Twu, C, H,. Fluid Phase Equilibria, 16, 137-150 (1984» Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 22 B.P. (OF)- 456, 611 981 Oilphase-DBR Table 3.7 BP Alaska Northstar Separator Fluid Well: NS-15; Cylinder TC1124 C30+ Composition 7.44 C18 C19 C,20 C21 .c~ C23 ç~.\ ë'25 ~ÎI%1At~>¡ C27 C28:;" C29 -c30+ , Mea!Mirecl,IIIW(9/ß".)ll.,.:,'" Calculated MW (g/mol) S.11191~~"g~J:I~b"GP~@~T.ø, . API Gravity AÝerage Gas GravitY . -çOl1billli"'tfc)ÍI (.~r , Contamination Corrected GOR COritânìfÍûìtlôÍI,Côìfêêted.API' , Group C7+ C12+ C30+ Compositional Data for Different Groupings Mole % Wt % MW 50.9 81.0 186.2 24.3 53,9 260.0 1.64 8.1 580.0 SG 0.83 0.87 1.03 B.P. (OF)** , 461 614 981 . Estimated with the Skimming Method, (Gozalpour F" Danesh A" Tehrani A, -H" Todd A, C" Tohidi 8., SPE Technical Paper # 56747, 1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C, H" Fluid Phase Equilibria, 16, 137-150 (1984)) Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 23 Oilphase-DBR Table 3.8 BP Alaska Northstar Separator Fluid Well: NS-15; Cylinder TC1141 C30+ Composition . ...'. e, 18,27 Group eC7+ C12+ C30+ Compositional Data for Different Groupings Mole % Wt% MW 50.2 80;8 186.0 23.9 53,7 260,0 - ~ 1.62 8.1 580.0 SG 0.8~ 0.87 1.03, B.P. (OF)** '461- 614 981 . Estimated with the Skimming Method. (Gozalpour Fe, Danesh A" Tehrani A, -H., Todd A, C., Tohidi B., SPE Technical Paper # 56747, 1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C. H., Fluid Phase Equilibria, 16, 137~150 (1984» Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 24 Oilphase-DBR ,--' ~ .~ .~. ,'-'" ,"'-"'" .~ ,-,. ~. ~ .~ 1'""""\. ~, ,-, ~. ~ ,-.,-, ,-- -, ,............. ,.-..,. - .- i--"'\ ,,,,"",",,, "'""'"'" r""\~, r-,'~, ~, ,~~, ~...~ Figure 3.2 BP Alaska Northstar Separator Fluid Well: NS-08 & NS-15; Cylinders TC-1126, TC-1142, TC 1124, TC 1141 C30+ Composition Comparison 100. 00 ~""'o,-'~w-"'---"-,.._~_..,_._--_._--_.._---'- ---~----._..._. ............ NS-08, TC-1126 -.- NS-08, TC-1142 - _NS-15, TC-1124 -NS-15, TC-1141 10.00 --= ... c Q) ~ Q) D. 1.00 --=8 ... .c C) .¡ == 0.10 --= 0.01 . . , , , ' . , . . , . . , . . . . . . . , . , . . . . . , . . . . . , . . . . . , . . . . . . . . ##~~ð~~~p~~~#~ð,~./~þ~~ð~~~~~~~~~~&ð&$ð#~$~~ð ~ðCi 'b# ð& ~(j' "OV #~ 9.# c/ r:!} ~~ Components Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples Oilphase-DBR 25 Table 3.9 BP Northstar Separator Gas; Wells: NS-13 & NS-09 C15+ Composition Component MW ç.t- " '; ii¡:'5;';:;:;;'!'/~:~~Qif; H2S 34.08 ~"L': "-";1~~'f ' C1 16.04 çl' ','~Q;A? " C3 44.10 ~.- 68;12:', N-C4 58.12 ~>" ", ::12~:15' N-C5 72.15 :C.~,Yi't ' ;' , '" ",8Et~ ' MCYC-C5 84.16 '.flžENe ' '-,&.t1 " CYCL-C6 84.16 Çt?::?'?",;,:" " , '1ÓÒ:2Q' MCYCL-C6 98.19 >:t(j~~NEt' , " .', '&2?1.'+' " C8 114.23 C~~"EN' , ,~Q6¡1t" ' M&P-XYLEN 106.17 è)..XVLENE '106.11 C9 128.30 JICjt:,,", \;'i~~~§âI~~ffip0\:( C11 147.00 'çî~ ,16t:Oò ' C13 175,00 C14 1.90.00 C15+ 206.00 A~era9C! Molec'ular WeiQ~t, Gas Mole % NS-13 NS-09 MM38810 MM33040 MM33085 MM38865 MM33082 , ~ i' " ;,~~:".~~;;:;/}~V#'!&;šäl~ 'i, 0.00 0.00 'c-'.C , 'f;'ÖI8~/::3~;;¡,;' Þ~'~()~~:"" 78.14 78.15 , :1:::~, ,7~82 ' 4.02 4.00 Ò~5t ' .0i51', 1.11 1.12 Ó.26~ " '0;26 ' - 0.29 0.30 , ,0.'1&', ' "0:20. ' 0.03 0.03 ,'0.01, ,O~O1 0.02 0.03 0 ,(tot;.' :;0:07 ,. 0.02 0.03 .O~ôQ>},'",O:ÕÖ 0.02 0.03 ,'~Of),;' "O:Qp 0.00 0.00 , 0.00 0:00 0.00 0.01 " " '0:00' 0:00 ' 0.00 0.00 0.00 ' , 0:00 0.00 0.00 0.00 O~oo 0.00 0.00 21.49 21,53 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 26 , ':i':¿~;¡:T;'~;'Øf; i 0.00 :]~f~~' <, :,'; 78.44 ,i/(g 3.81 o.~,,' 1.02 " : '0::14:, 0.27 '- o.,~t". 0.03 Ó¡01 0.03 0.01 : 0,03 0;00.' 0.03 0;00 . 0.00 0.00 0.01 0.00' 0.00 O;()Q 0.00 0.00 0.00 21.40 -';~::;,..':j'i~{'c'~i:!,g1;¿';, :-:' 0.00 ,': ¡'1:ê!~~}!'l:}':, 78.34 , ,té3.} . ' 3.85 O~55' . 1.05 . :Ftt26 c 0.30 q~4,>' >" 0.04 , ().O1 0.04 ò>f1 0,05 "G.bi 0.06 ,0:00' 0.00 (too 0.02 'O~OO" 0.00 ,9¡00' 0.00 0..00 0.00 21.58 c '~?&t;':';7:~::; 0.00 > ,''Ø!$~': :' , 78,61 ,,:!;~', 3.94 ,O~55 1.01 :'Ö~23', 0.26 ();~9 . ',' 0.03 , (t01' 0.03 'à:ö~ '" 0.03 ,Oi()(j'; 0.04 ., ,,0:00< 0.00 0.00' 0.01 0.00' 0.00 " 'O¡OO 0.00 o.QQ 0.00 21.41 Oilphase-DBR Table 3.10 BP Northstar Separator Gas; Wells: NS-15 & NS-08 C15+ Composition Component MW ( r ( §'g~>,:;\:"',,::, '. . "".!' ,. ,;:;':. ,:':}4~M~;~:,:: H2S 34.08 ,.<t~8~ôif".';':;:':~' 16.04 , .::.~Ø~Q7:':';~:: 44.10 :,;,:';~ø.~'2';:X,::i;',': .' 58.12 , ':~"\!2.;tØ:.\f;: 72.15 C1 J;~~::< :' C3 iqç4;::;L:\: . N-C4 ,~$::...:. N-C5 ( r ( ( r ( ( ( ( ( ( ( ( ( ( ( ( ( (. ( ( ( MCYC-C5 84.16 ~J;"~I;~t:' ", "/"": '(~;78,~1t'1,>:" CYCL-C6 84.16 C1'>i:":'<::"', :'(,.,<'è'¡,. ", too'-~o MCYCL-C6 98.19 TOL1)~NÈ '. ' '92:14' , C8 114.23 Ç!!~~N~~tl,;,. . ':.. .' .10~.47;, M&P-XYLEN 106.17 ()~XY~ENE ' ')96~17: ", C9 128.30 ç1cr: . t34~OO . C11 147.00 C:12.''',. , "1,61.:00': . C13 175.00 Ç1~ ' '19Q~OQ" C15+ 206.00 Averaqe Molecular Weight NS-15 0329 0343 Gas Mole % NS-08 0342 0327 '/,:':.~;~~y.::. ; ,':: ' , i.t:ii:§~~~;~'Y~i?::; :};~:h!.@~j;t)¡:~;E;;: 0.00 0.00 0.00 ; :' ':A"'1,~~~'~: ': ,.\: ""¡'::',!~:~'t;;Y":' "', j",<>,<~;~~(,.,.:~.;::?,,: ; 79.14 78.36 78.53 ;,>~}:lJØ~:" :::J::<::t-~§2; ::,,' :~, 3.75 3.70 , ".: :;:;:;:;\Þ.~~1>,::;,:'c ' ~;:'::';"i:,('Qi~~:ij" ',' ::.:", 0.96 0.94 " ,:f'Qi?~\.'r::i :.':; ,', :""(q~?1': ,,' ", 0.25 0.23 , ':' :9~:1§F:(, " ' .ot~~' 0.03 0.02 < :" :;.p~Q~:: >;,:;' . 0.03 , :"'>::;9~~~':<';';+:' 0.03 :Q~Q~': 0.03 , ~:OJ~9:', " 0.00 ',(tOo, 0.01 , '0.90:' 0.00 ,0.:00 " 0.00 . OX~Q 0.00 21.38 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 27 j;::";i:;§~~§;,;j.:;,'\;' 0.00 ¡,;, ':;l~~~,~: 79.20 ,"::;7;i,~~:,:,' :-::,<; 3.40 3.37 :, ::Oi~\,::,":::' ':':: .>',)~4~,~: ' 0.81 0.79 , i ,', .:()lf~:',:::¡': ','; ,','.O~:1l:;::::: 0.19 0.18 ":';Q;~~/';;;, ,., "',,,,9.1:~:::i:, 0.02 0.02 '>Oi01/'\; 0.02 ""O~()5 " 0.02 0.01, " 0.02 , J).~(),O ,,', 0.00 0.00'" 0.01 Q.OQ 0.00 " 0;00" 0.00 '0.00, 0.00 21.07 0.02 , ''-''òi04i.,¡O' ",' 0.02 ,0.<)(',' 0.02 'Q..P~L" 0.00 ,,0.0.9 ' 0.00 "O~Q(): 0.00 '0;00., 0.00 :O;OQ' 0.00 20.99 0.03 , :;':'0;00" 0.03 ""Ó.9~ ' 0.02 ,q.OQ;", 0.00 ' .O~O() 0.01 " O~OO 0.00 ,0;00',', 0.00 ",,'O~QO"" 0.00 21.30 Oilphase-DBR Table 3.11 BP Alaska Recombined Reservoir Fluid #1: NS-09, 5100 psia Psat C30+ Composition Compositional Data for Different Groupings Mole % Wt% MW .1;7';2 ,5$18 187.9 8,3 40,2 262,7 0.58 6;2 580.0 - --- . Estimated with the Skimming Method. (Gozalpour F., Danesh A., Tehrani A. -H., Todd A. C., Tohidi B., SPE Technical Paper # 56747,1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C. H" Fluid Phase Equilibria, 16, 137-150 (1984» Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 28 Oilphase-DBR Table 3.12 BP Alaska Recombined Reservoir Fluid: NS-09+NS-13, 4850psia Psat C30+ Composition Gas Liquid Component MW Mole % Wt % Wt % 1;Q~Lc. ' ,,' '~;Qt -.:-", ~'::.,:" ~;:13,','.. ,'- : :::.':.Q;Q9:";" '. ,. ::-i,.::.:;~~:~~t>:~-,.::. H2S 34,08 0,00 0.00 0.00 "2 . - <:2~.()1 ' 'O.7~'. >0;00:., ..,- ~ :' ;:: 0~30 . , C1 16.04 69,25 0,00 15.15 C2, :,30.07 ' .:'~:8,85~: ' ':!~Q.qg;'..::,', <.~;~. C3 44.10 6.31 0.13 3.88 J~::, . <.':~$â:12, "-;',::1.~3":>< .~:':,)~;O~09';:><' ,'1;-03 N-C4 58.12 2,87 0,39 2,53 I:'Ç~(": ",: ..,', ~',.<::~.t5" ::', ,0.$8.- '.., ~,:';,:,;~)Ò.51.:' ',':,1;3(), N-C5 72.15 1.23 0.92 1.80 C~ :~'. ',: ,- " ;ë'àti.~" ~:~:)Jo.5: . <.<':2.63 ~.,~ ;>:...?95 ::>. MCYC-C5 84.16 0.19 0.73 0.69 ~I;~E ""':':7.~t11' ':".0:07, :. . ">0;21:' - ~,¡;Qj21'<' CYCL-C6 84.16 0.20 1.04 0,90 C7' ". ' ?'~100:2ÓO:39 :" '3.60.: ;' "2:~' MCYCL-C6 '98,19 0.182.23 ' 1:70 tQ'~§~~'/:;)i';,;ii,:/:i;{ :i;W)~~l~~¡i1~i~i;;i:L;fi ,:,¡:;i;;~.~Þ,;.~~~t;~?î';:;~~;: ";~~]~0;¥;~§ï;ttii;¿¿!::j;jMà$?4l!J§jØJ!~~,ii::i2;¡~~;~ftìiÂît~;~l~j£:f ¡;i:sg;~;~~~ii~i~~)~f~ C8 114.23 0,15 5,05 3.52 1.78 C2-BENZENE ' 106.17 0.00 , '0.16;' , 0.'10 . . , 0,06 ' .~. M&P-XYLENE 106,17 0.01 0.84 0.57 0,31 O-XYLENE ,106.17 0.00 0.32. 0:21 ,0;12 C9 128,30 0.05 4.95 3.30 1,48 C10 ,134.00 0.02 '6.86 . . 3.84 . 1.65 C11 147.00 0.00 4.83 3.15 1.24 C12 . 161.00 0.00 ,4.40 2,86, 1.03 C13 175.00 0,00 4,89 3,18 1,05 C14 190:00 0.00 4.63 3.01 - 0.91 C15 206.00 0,00 4.24 2,76 0.77 ç,',::;, ,~::':;,\' ::,; ~:;: ,<:,,;\!';, :'i:~::(S;i;m;-Qj5{;, , ,: ",;:.j¡;; ::,ßF()~òQ:.(,;;'i;:;:i,{::~)::.\~i.:r;~;7l"(i:.::':::;,\':E(; ,.~G~'::;]~(:;g,;4§È!1F);:ài,: ,;i:¡is;;i'f;::\~¡§4:ii: ';,~" C17 237.00 0,00 3.48 2.26 0.55 (;~~:3';;¿}:';;::';'r:!\:i;::;':'~J":; {2f'tt;':itì~~!:Ø,9á;,,:,;:,,y~¡.)i!:;::::f;~1;,~9;~):;':F:;:f';f;::i;; }k;í,:~~;\:.)~,§~::*,i:~'>::;::,:;: :r?S;~';'~~~1~$~Y¡fß~&{;;U,j;~¡~:t¡::\Ó~:f;f::~«/i~1:?~!\:(~~(\:~1:;;0;::fAf~ii~j;~;¡~\ C19 263.00 0,00 3,30 2.15 0.47 2.97 ç~q,'.,.,: "i.. "'~',': ,':.:,:":,'~:,:';i,:,;,,,';::;,~::;\:g:t',Iþ:Q:Lji::;::;;:Ji':~1<~\:iþa~':::':i;::;\;i:; :¿!}&;'t::j:¡,~;~ph:;;<ft'~,>;;:":;fM:j:¡§giÜ::,::;;Ü::;~";:,¡~~:;!:,(Q:~~¿;1?øi¿::A,i;r::~!iAJi¡::;i;,,:i,f;;};:;~~H¡;A C21 291.00 0.00 2.62 1.70 0,34 ç~2",';:';:;;i ':'","<;~:!;:::~" ' ,: :" ':;<i;1f:)~Þ~;óØ;:.:i:::;+::~',:::i:, ';i:\;.;Ø~Aö:'1:~'::}i;A, 'S,";'i![;~i:~;3~ri".,h'::,:" ':'{;::<::;;;~' 1,¡~%'¡Ì;;;j~}:>i;;i::~!;¡'Q:~"),:S:!::';:j,'., ':;;,~:t¡!j;:k:\;':':6;;~f;j;;;;~;..tt, ~~:;::~P;L-".;:::: ;".:,'" , ;>~.::j:~;~:~gg':Li¡'à.';;, :;;X¡;;ri~,;gø"j'~:i')'Æi ;i\:;j;:~~~~::i:,;::.;;:]S i}':,:,Ù;\i;¡;:i:~;~f:;¡:~:{;:::;;:¿igÞ~~i¡::.j;';V;:: ',;:i.;-~:;:;i:,,;;þ;¡;":jtj¡;';::)[:6;i;i C25 345,00 0,00 2.03 1,32 0.22 Ç;?~i';¡';:)': ~"''',,'' '" ,::,:::~5~~9P.~:''J_,'' , ;',!, ;,,; 9~QØ':;::,:,:;\<';;;;?;\i'?(:!;':;Øt,;.:i;:: ;è;:I;I,J11(iØ'ì{~<;;Ùj::[:~t;:;:"Ø;¡17:~~:;:;::j;;-.,: C27 374,00 0.00 1.74 1.13 0.18 ç2í('lh:,' ',' ",' ,}t.'3~~óO,::," , ,.;/\,;0JtiçtÓo';{;"'"::,i.:i\;l\$2;:,,:;:\\:;')):;i;;;;~,~J/"),,:;,,:;;:,:':i'.(()¿113 : C29 402.00 0.00 1.58 1.03 0.15 ;~~~~,~~~:~W"¡~¡~9'~::;:; :;:~~::~~:,;J:;,;/;,:,~ '.);:,:;,::~:QO,:'-' {;::,: ': ,~:;/i'¡~1l~1, ',,' ;' i:(:;:i:~i~:(;;\;;i,<ii:';::r>,~jß::Ù",':,; ,. Calcula~ed PtII,\'If (~l~ol) , ,," " 176.7 ~iI:'91(! :$~g~Flâstt C;O~,@:~1:D: . . .'(!Ø3!Þ.1~:' , A~I G~a~ity "" ,,'" Aye~ge¡G8sG,aYity", '", çi)nþlm;rt~tf~'''(~>~}t);,. ,',. ',. ,'. Contamination Corrected GOR ëôótåî1íióétióÎ'I'córrèctêdAPI- ' Group Mole % . :.,~~.:~~:~ ',-';\~. 0.00 , '~-o.~, 54,53 , ::~ :.6~~7/':;.,.':'-;:: 5.08 , -;":\~i~b3~"?':::',.~: 2,51 ;:'t;~? 1.44 6,72 5.88 -<:.,'ç, Group C7:+, , C12+ , C30+. Compositional Data for Different Groupinqs Mole % Wt % MW 'l8.7, ,,62.0, . 191,0 . 9.1 42.2 267.1 0~76 " ' 7.7 ' 580.0' SG , 0.83" 0,87 1;03 B.P. (OF)** :' ,\472", 626 ',981' ' . Estimated with the Skimming Method, (Gozalpour F,. Danesh A" Tehrani A. -H" Todd A C., Tohidi B.. SPE Technical Paper # 56747, 1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C. H., Fluid Phase Equilibria, 16, 137-150 (1984» Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 29 Oilphase-DBR Component CO2 H2S N2 C1 -c2 C3 Table 3.13 BP Alaska Northstar Recombined Reservoir Fluid, Well: NS-08 C30+ Composition MW 44.01 34,08 , 28.01 16,04 30.07 44,10 Gas Mole % 6.36 0,00 0.79, 68.99 Q;79 6.26 'ft.jif¡;ji:;:ß ' MCYCL-C6 ToLÙENE C8 C208ENZENE M&P-XYLENE o..XYLèNE C9 cC10 C11 C12 C13 C14 C15 Ç16-~ C17 Ç'Ï8," C19 C20 C21 ç,n, C23 ~~r:;~;:~t ~ -°," ~ \ C25 oaf,,:' C27 C2â':, C29 è:3Ø+':: '. ':';"" ' '.i'" , '.' " " ¥~tI~""".(g¡l11ol) , ëalculated MW (g/mol) ~r~i.'S.FI~,GÒ.~/@:gTÔ; ': API Gravity AvefBgëGasGravlty, , , Ç~nti!i.tiøÞJiIVt%)~, '" ,,' '" Contamination Corrected GOR Cöntamlridon COrrèdedAPÎ ' Liquid Wt% 0.00, 0,00 0.00 0,00 0.00 0,07 2.48 0.05 0.76 114.23 0,17 5,58 106.17 0.00 0.33 106.17 0,01 0,83 106.17 0.00 0.52 128,30 0.05 5,27 134,00 0~01 6.56 147,00 0,00 5A2 161.00 . 0.00 4.1~3 ' 175,00 0,00 5,41 190,00 0.00 4:82 206,00 0,00 4.65 '):;~22~qQ~,<, ',~~' ,ifli)Pi{) - ;~, ,; "",~4;()O ,,' 237.00 0.00 3,72 :25l~OO. ",Ò~OO, 3.71 ' 263.00 0,00 3,51 275,00 0,00 2.83 291,00 0,00 2,68 '305:99 : ,'_'Ji~9Ø2.43', 318,00 0.00 2,30 : ,¡;"':':~¡?i~~~!~:¡:~~~1t'!)'l'f '~\\:h,{r':1'~;@:~!~g~;;tJ12j{:i';i ',"(i;{'i0fi#;Q'i-\'~':, 345,00 0,00 1.99 '~.t1ô,:-'\ :,.-:'~ZÒ;ÔO; " ,':~;6!f" 374,00 0,00 1,78 , 38ë:Oó .'0:00" , ,1:68, 402,00 0,00 1,57 "5âöiÒO::' "''¿.'Ò:ÔO:i,:' \~,:J::<1';ä5 : 25,8 ':(.450"i9" .' \".,~ , 39,6 , ' ",0;89""". .' Qead Oil Bå$js .' 173A , (M~tM~f:' ¡' Wt% .4.04 0,00 0.32 15,98 3.82 4.03 1.85 0.55 3,79 0.21 0,54 0.33 3AO 4.14 3AO 3.03 3.39 '3.03 ,,) ,~," 2.20 1.78 1,68 '~t52, 1.45 ::,." tr;'j1'¡~1}:~'~~'" 1.25 ;1;~' 1,12 ,'{OEi, Overall Mole % 5.09 0,00 0.63 55,16 7.03 5,06 OA6 0.36 0,32 'Q;2S' 0.25 ':;~;~"\~~"::Diji:i?I\;~<; .",~:,. 0,20 . ',t};16, Group Mole % 5.09 0,00 0,63 55.16 7.03 6,85 5.99 2.93 -:"'::~¡:::fi:':~:~1¡;:r~~~;)i~,':: ( '*""\";~:' _\ ':~ ' ., Group Compositional Data for Different Groupinas Mole % Wt% MW SG :};'(SÇF(BBl): : 8,6 ,0.46 39,8 4.a 254,9 580:0> 0,87 , .',H>3" . Estimated with the Skimming Method, (Gozalpour F" Danesh A" Tehrani A, -H" Todd A, C" Tohldl B.. SPE Technical Paper # 56747, 1999) .. Boiling Points Calculated using the Twu Correlation, (Twu. C, H., Fluid Phase Equilibria, 16, 137-150 (1984» Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 30 B.P. (OF).. 605 ,981 Oilphase-DBR Table 3.14 BP Alaska Northstar Recombined Reservoir Fluid, Well: NS-15 C30+ Composition Gas Liquid Overall Group MW Mole % Wt % Wt % Mole % Mole % 44.Q1. '.- 0"" "-,,' -"'6:~O 'é>->","", ",', "Q';OO" ,', :'" :: '>~;65"o' "'::",'>":4~:" ~,'i;: ',~:~'.,o,')t~?~:>'::,c,- 34.08 0.00 0,00 0.00 0.00 0.00 , .- ":'2Š:Q1:~;: ",: " ,\:fi~':-:" :"::",Ö.òtj'::',,:;"~: :~\,:"¿i);šF,,~,::)\:;{:'}'b;65::~:;:"";'.': ::,-"::Ó.~5;:->':,é~:, 16.04 70,11 0,00 14,34 53,07 53,07 C2'.; , 'c30,Ó1~ : ,',<:-:9.01'--': '>'";"'Ò;OO'_::-:"~:4f(;~,::':~~":::':';6.~","; ,.;:'~oi,6:~2" C3 44.10 6.57 0.13 3.78 5.09 5.09 I~;X: ,,<, .- .',.>:_~~j2}'-::: ;:,"~~~2"::'~"'~ .;:;:,-<Q~1p.' :." ,':': ~!?:;"1'~:;..!;:;,;<~:,~,,:;;::(;.j~~zj-,:,:":~';:>:i~'::;~()4"~?J?E N-C4 58.12 2.88 0.49 2.47 2.52 2,52 I~;¡tf/:,,:L.',; ,~, ">!'?~~t5'::;:',:_. ';,"jj~t~:~ ", r:::q-:8IL';"-~":',~>;::~fI~~_';'~:':"::',:"Ò;ø~~' "'. "i':':>~-~;~~~,- N-C5 72,15 0.88 1.17 1,61 1,33 ~<:;~:/:"./;~':': ' ;~;20( , , ';::Q.~$'~' " ' ~.~ , '2~72}',::,'..';, .- :";i87{',: " MCYC-C5 84.16 0.09 0,83 0,67 0.47 ØENZE~~' "78,'11" ": ".'.0,03' '>.;0.22':0:,' ,0:1,8:-0:1-"-" CYCL-C6 84.16 0.09 1.17 0.90 0.65 c't:'::>,,'.~,:' '100:20' "Ò.'t7 :.\tt98.: . ""':. ',2¡Ø6:;""'~"";;'i;~1:1t5i";'':''''i MCYCL-C6 ' 98.19 Ò.Ò8 2.63 1.9Ô 1.15 . TOLUENE" 92.14 . OJ)~' '..().84', ,,{).60':',,:'" "O.3~- C8 114.23 0.06 5.44 3.82 1.99 IREI~i\\'III:~'i~~li~Ii3.J;'1\'I~~s.J¡"~ì\l'iII.\tl~.''''''¡~'~'%¡.11~"i_\\'t'lt.'I.'.1J§¡,1I~¡I~W#.Jfj.r.lflf¡ìKfI¡~.i"- M&P-XYLENE 106.17 0.01 0.84 0.59 0.33 O-xYLENE 106.17 " 0.00 O~52 0.36 '0.21:) C9 128,30 0.02 5.16 3.57 1.65 C10 134.00 " 0;01 - 6.15 4.23 , 1.88 C11 147.00 0.00 5,05 3.47 1.40 C120~OO" '4.553.'2" ':1.15, C13 0.00 Component 7.50 C22 C23 C24 C25 C26 C27 C28 C29 C30+ Measured MW (g/mol) Calculated MW (g/mol) . Single Stage Flash GOR @ 8TD API Gravity Average Gas Grav ty Contamination (wt %)* Contamination Corrected GOR Contaminatlòn Corrected API 318,00 331.00 345.00 359.ÖO 374,00 388.00 402.00 580.00 Group C7+ C12+ C30+ 0.00 2.20 1,51 0.28 0,00' '2.00 1.37 0.25- 0,00 1,91 1,31 0,23 0.00 1.63 1.12 0;19 0,00 1,71 1,17 0,19 0.00 1:62 '1.11 0.17 0,00 1.48 1,02 0,15 2,51 0,00 8.47 5.81' '0.59 0.59 24,6 167,5 59,4 362:7 (M3/~ 2036 (SCFIBBL) 40.2 0,850 Dead Oil Basis Uve Oil Basis (SCF/BBL) Compositional Data for Different Groupinqs Mole % Wt% MW 20.5 63.7 184.8 9.7 42,1 258.1 0.59 5.8 580,0 SG 0.83 0,87 1.03 B.P. (OF)** 458 610 981 . Estimated with the Skimming Method, (Gozalpour F" Danesh A., Tehrani A -H" Todd A C" Tohidi B., SPE Technical Paper # 56747, 1999) .. BOiling Points Calculated using the Twu Correlation, (Twu, C, H" Fluid Phase Equilibria. 16, 137-150 (1984)) Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 31 Oilphase-DBR Table 3.15 BP Alaska Recombined Reservoir Fluid, NS-13, 5100 psia Psat C30+ Composition Component MW Gas Mole % Liquid Wt% Wt % Overall Mole % Group Mole % 'C2 C3 1-<::4 N-C4 I..cS . N-C5 C6 .',' MCYC-C5 BE~È CYCL-C6 <:7""'>"';''':"';- MCYCL-C6 TOLUENE C8 C2-BENZENE M&P-XYLENE O-XYLENE, C9 ê~~¿~i.¡ .: C11 C12" C13 C1~~>{~,:. ;::;:: " C15 Ç1~::' C17 Group C7", C12+ Compositional Data for Different Groupin~ s Mole % Wt % MW ,'17.5: '~]>:,:'189~3' 8A 41,0 264,6 0.66 TO 580.0 B.P. (OF)** .468'. 622 981 C3o+ * Estimated with the Skimming Method. (Gozalpour F" Danesh A" Tehrani A, -H" Todd A, C., Tohidi B., SPE Technical Paper # 56747, 1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C, H.. Fluid Phase Equilibria, 16, 137-150 (1984» Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 32 Oilphase-DBR Figure 3.3 BP Alaska Northstar Formation Water Collected at LP Separator Compositional Analysis MAXXAM Analytics Inc. Glass NJA ¡;':',I'!:¡:'('1,¡ë.'W:t1:t\-' P.;'.'.:...~ .t:..~~~.;.::.':;¡.:..,:; ~':'.','11 :.::'1 '>\::I!:[< DBR Resealdllnc, C:'r~'';:\,v8F,\:'' DBR RESEARCH A_'_~__--_._._----- .---..--- 1t\~X~"':':;~\~" W A TEA ANALYSIS 02.28273-02 l~~:-~.: I':'.rv~'\\.~!t;:r t.::C' ir.r.-\:'c' NlA DBR ------------,----~- ----- N;1!(1.~f':~'Þþ\¡lf ¡/ì::~\';~l,":;' '~''!:1'I',t\r.;r.:(<:.( DBR 2002.63JOB:20023132 :~;.;~~;~~'!~:s;-;-;~;:;;;;;t~.mmn.....mm---...m.......u... ""'''''''''''''''''--'''''''''''''''''''''''''....................--........-."......n"--'_"'--"''''-''''--'''-'Un'''''''''''''''--'''U'''''''-''-''''-''''''''''''-..'''''''''''''''''''''''''''''''''''''''''''''''''''''''''''' r...a h.~'),"""'I.'}' :.t!l:Q1<.~(1 ..-.....m' ,\"'*:/,'l3,(j! ....-mm. INf~n.'úf':~ f'-',),rtl .......n..... -....... ...... f;.![ Tit!]:! N'J Mtit~i:1.~~ú'{';~j' r'~ dñt \:i:ë~p~;~;;.~:~rv~~.~.m~~~~..~.~ ~~;;~~~r;.;.,~.~;k~~~mm_m_~.~nm ! NiA NiA rJJíf.1».r~~~"?:. t;: '-¡ :~;;~St;;~;;.;;~.~....~..m.-... m--;;,;;;~~J J --.----------.--.--'m.--mm--.-- {.~";~r¡~,')"; ¡ . .k' ;"'J~\..'!':~~~1 t-f.,r.:.':) I 'ï\.;;~;';'::;;'-------- ';:;:;;;;;,..........m :----- ,;ttð.~}i.t f..r....::,i,t¡;;:i 'fíF~ , ..........~...........".. ~ .:;''\V"r..''~ 2002/04/11 2002/04/11 _m- J.).:.r~;., ~1' ~(I~'~' Sr.,.., ú.,-(',.).$,J.'1'1)~.tEt~Î D,~.~:1\!1'>."I'¡\...;.I,;' C}.jr<:~~,;'þ"..,rt~l,.~ ( r CATIONS ANIONS m67----m+----mm'------'~fZ7Õ-t-mmmm--m~~ i Ion Na 1280 55.6 K 10.4 0.3 Ca 19.4 1.0 Mg 5.8 0.5 Sa 0.3 <0.1 Sr 2.8 <0.1 Fe 0.1 <0.1 B H+ HC031 248\ 4.1 504 I 53-41 1.1 C03 I <11 <:0.1 OH <:1: <:0.1 H2S I ABSENT: ( ( ( ( r ( r [ ( ( ( ( [ ( ( ,~ ( ( ( ( , l L Na 101 " .. I , : I 1()i! logarithmic Patterns of Dissolved Ions (meqJl) 10 Q1 .' . ¥ "4""'.1,1....-. . , I , I M9"'~'~: ,_. ....~.. 1'''''''4 ~ """"""""""",,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, ~,~ ..............-................-...........- MH~WADL --- .J",1.:)!,,~t Total-DissoiVed Soitds (míJ/L) 3610 ............................................ 3160 .......................................... """""'ôltiM ,{i; I}'C Caket'nwc: r--------------'-- r(A~,~:,:,=:,:~:--(~j ___1.002 ____,L33~ ~m~~~,~~ R""'a<:~" in<.'e> 6.8 ....................................- 1.73 .............................................. ~JW!d pH ti~~.1:}'t1!!¡~ :&25'( 72.3 --~-_.--~~. 1:.,ta:H~:iA:¡. .! ofa¡A¡Xt.cj,i1t~1".4$ C~(;O-', !:.J¡;t,it.l CliCl.}" ("'£'''U ---.--- -~------- Mt-:::.{ha!1of ~W'~.4J î),1 ~ G,,'= \r~'!J r,,!,;li 1'.. i"'1?itl røtalM" {"'f!,C ~--~-..............----- ",,~M(}/-I ~~ I': ,i! 1~ . ~:'~i,1 CI ~~ , so" .,-' c03 ::¡!"t(jM<!!f.<a.'I!'( j¡:~f)m"" i1!(~'1A\:'r;P¡¡ ~),!fe(F'¡I'MI<)t r;I.It).!'\'I~If;t¡s f\f:tIJIl~ !~ræ" ~I(¡¡¡"m;¡!~stcd Iì<mar-'s; LPSEPARATORVvATER Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 33 Oilphase-DBR Figure 3.4 BP Alaska Northstar Formation Water Collected at HP Separator Compositional Analysis ~~ X!,_! M__~nalytics JI!~~- GIas!; Nt" -- --.. ~ ...--"....----- '::'~'-'1I~(r,~.. .i...,\<-,~:t'; DBA Resea!ch I!'\C, ¡~\~,",\\.!,.i;.¡:i* DBR RESEA RCH WATER ANALYSIS 02.28273-01 ~~ ,. -- --- ,,liD N/A -_._,------~_...._----_._~-~-_. - ----- ~---.__._-~--~--_.._-_.~- DBR 2002-ô2JOB:20023132 ,\\i'1!~ '.-( -;;.....(:.þ~~' ~- -'--'--'--'-'-'-'-'~---',--,-,-- - f'~'.1;".\:,:.-:,\'(",}' :''i;:.''r"ð-'} 2002/04/11 2002/04í11 CATIONS ANIONS Ion meq/L mcqlL Na 6390 278 238 K 42.3 1.1 22.4 Ca 87.0 4.4 S04 154 3.2 Mg 12.4 1.0 C03 <1 <0.1 Sa 1.0 <0.1 OH <1 <0,1 Sr 13.0 0.3 H2S ABSENT Fe <0.1 <0.1 B H+ 104 Na . Logarithmic Patterns of Dissolved Ions (meq/L) 10 0.1 IC~ 1Q2 I ' I ~ ' Ca _. '-'-- - , " M¡¡ .."'.', ~... -., .. Fe :.-;~ "~',~.1 D!'l\\\.W''.t~~ }i:".'\:~,;:" DBR - ------------ ._--------~.._-_._---"' :-~S~'I.:~ l~:;¡!t:~.~:.í ,-::-\I~f ~-~--~- 1-;,.,'jPP.u:'sI,n"..,...-- --,,---~--_.~.- a,a1 ,:;:rilIU!' T'~~," MHIRW/LDL ------------~- t{,."..~T,..~~ ::~';'Î,";:~.v,. 16700 -,------ ----._.._.__.~ T Olaf DlssolYed SoIÞ.1s (milll.! T Q! It! Suspended SoNd;; (mglt j 1.011 _._- -'----'''--'-''- Po{.'J;::!:l¡-..,(~Dt..~1i!ti' ~~~S.t.)1 ,,~~ J.~u . ---_w_--~§§ f<"'~l ii~1:dr¡-(1-$5 Jt.:o C~ 'fú~. Ü/;£-i,{) Mo-1!hfl'~o'Jf {wr\J,i J()~~f h; ~m';~U 10 !QZ ;;rÎ(1œ{jr.m~~,dk:¡te 1"0 ~~d(tç'fIi);r~rT. aI:;.r)~ WIJ:~ei~~..,')!' f: I.Iß ,PflS fit; S Í'll'f,1JiJfk'). HP SEPARA TO=1 WATER Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 34 1.335 fìë.'~$!;t,;.io't." :r,;.j~~ 7.6 0.403 fi(.)'&.b~"'1!~" In(iJJ .?i.;'75' ( --_____JlfQ r Ofar ,A; (¡;¡Ílr:',~~' AJ!: {',~aCÛ:~, J'm;vL O'í^ Gt~ {m!l"'l/ r(lI~JMf1¡'f~:.'!.., Ú'''''¡W;J.l~ 103 104 CI .. 'j ¡-- HC03 , , ........ ..--. , . :..;,.- 504 .r-I' '^'3 B~$cll~i:e~t O"!W!0~~~tJlSk~h,~ Oilphase-DBR Table 4.1 BP Alaska Recombined Reservoir Fluid Well: NS-09, Field: Alaska Northstar Constant Composition Expansion @ 254.5°F Pressure (psia) Liquid Volume % (%) Relative Volume V r=V toN SlAt Liquid Density (gIcm3) Compressibility Co (10"psï1) y- Function Value .', , Psat I.' ¡ . , ( [ ( r ( ( ( ( Vr = a+ b exp(-P/c) a= 0.87315985 b= 0.66771594 c= 3063,5963 V-Function is only valid for Pressures < Psat Equations for the Relative Volume and Fluid Compressibility are only valid for Pressures> Psat P - psia Psat - P Y = P(VNsat - 1) Co= - d(lnVr) dP ,. l ( ( r t ( ( ( t ( l ( Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 35 Oilphase-DBR 2.90 2.70 2.50 2.30 CD E ::s ë5 > CD > .. ca - CD 0:: 2.10 1.90 1.70 Figure 4.1 B P Alaska Recom bined Reservoir Fluid Well: NS-09, Field: Alaska Northstar Constant Com position Expansion @ 254.5°F - - - ~ - - _:- - - ~ - - ~ - - - - - - ~ - - _:- - - ~ - - ~ - - -1-"- - ~ - ~ _: - - - ~ - - ~ - - -1- - - ~ - - ~ - - - L - - -L - - - I I I I I -- - ì - - -1- - - T - - ï - - - - - - T - - , 1 .05 --,-.1----1-- --1- 1 I I I I - - - ì - - -1- - - ï - -I - - - - - - T - - . I I I I 1 I I I ---1 -T -~- -1-- --+.- -1- - - +- - --I - - - - - - -+ - - - 1 I I 1 1 - - - ï - - -1- - - I - -I - - - - - - ï - - , - - - ~ -:- -- ~ - ~ - - - - - - ~ - -.1 .00 I I I I I ----1---1- -+-- -1----- +--. I I I I I - - - ï - - -1- - - ï - - 1- - - - - - ï - - , - --1---1- -j--- t -__-"___1___1-_- -.I.-- I I 1 I I ¡ I I - - - ~ - - -;- - - ~ - - -I - - - - - f - - . 0 .95 - - - 4 - - -1- - - 1""" - -, - - - - - T -- - J - _1- - - L -- _I -- - - - J -- 4800 I I I ¡ I - - - , - - -1- - - r- - -, - - - - - , -- -1- - - 1""" - - , - - - - - - T - - -1- - - r - - , - - - - - - r- - - ,- - - r - - T - - - 1 1 1 1 I 1 1 1 1 1 1 1 1 1 , , I I I I I I I I I I I I I, ---'---1-- , -ï- ----,---1----'--,------,---1---,--,----- ,---' -------- - - _.J. - - _1- - - L - - -' - - - - - J. - - _1- - - L - -..J - - - - - -..L - - _1- - - L - .J. - - - - - - 1.. - - -.! - - - '- - _...:.. - - - I I I I I I I I I I I I I - - - , - - -1- - - , - - , - - - - - T - - -I - - - , - - , - - - - - - T - - -, - - - , - - , - - - - - - r - - ,- - - - - - T - - - .1 --1--_1-__.1-- J- -I---L -...1---- j __I___L__.1______L__--1___,----'--- I ) I ¡I' I I I I I I ¡ I 1 1 1 1 I 1 'I 1 1 I 1 1 - - - ...I - - -1- - - L - - --1 - - - - - ..L - - -1- - - L - - -J - - - - - - .L - - -I - - - L - - -1 - - - - - - L - - --1 - - - ~ - - ..L - - - I I I I I I I I I I I I I - - - ï - - - 1- - f - - -I - - - I I ï - - - - - T - - -I - - 1- - ï - - - - - - f - - -, - - - ,- - - - - -1 - - -1- - - .I- - - -I - - - - -..l - -1- - - t- - - -I - - - - - - --L - - I- - - -..J - - - - - - +- - - .-; - - - I I I I I I I I I I - - - ï - -. - - f - - T - - -I - - - I - - ï - - - - - - ï - - - - ï - - ï - - - - - - I - - -, - - - - - I I I' I I I I I I I I 1 I I I I I I I I I - - - ", - I ì 1- - I - I I" - - -I - - - ï - I - - - - - - "I - - - - - - - 1- f. - -I + -- ~- - -I - f. - --I -- - ~- -t +-- 1 I I 1 I 1 I 1 I 1 - - - 1 - -" - ï - - -I - - - - - - - - - - ï - -. -: - - - - - - ï - - -I - - - 1- - - ï - - - - - - I - - - - - - -t --]- - -+ 1 ¡-.. -4- t-- I I 1 1 1 I 1 I I 1 1 I - - - -+ - - -1- - - +- - - ~ - - - - - -+ - -1- - - t- - - -i - - - - - - + - - -I - - - t- - - -t - - - - - - + - - --¡ - - - - - - -+ - - - - - - J - - _1- - - l. - - _I - - - - - - J. - - _!... - - J - - - - - -.1 - - - - L - - J - - - - - - 1. - - -' - - - - - - 1 1 I 1 I 1 1 1 1 1 1 -1- - t- - --¡ - - T - - - - - r - t -I -- r - --r t- - I L _I - - _L - ILl - 1 I' l - I 1 I: 1 1 1 I I 1 1 I - - - ~ - - -:- - - } - - ~ - - - - - - ~ - - -: - - -: - - ~ - - - - - - ~ - - -: - - -I P sat = 5095 psi a - 1 1- - - T -¡ - - T --I - r - - - - T -- 1-- -- r ~ ~ ., ~ r ~ -- - .1 - - -'- - - I- - - -1 - - - - - - -L - - L - - - - - - - j - - -' - - L - - J - - - - - - I- - - -' - - - '- - - -'- - - - 1 I 1 I 1 I I 1 I I 1 1 - - - ì - - -1- - - T - - ì - - - - - - T - - -1- - - ï - - ì - - - - T - - -I - - - r - - ì - - - - - - T - - -¡ - - - - - - i - - - 1 I 1 I I ' 1 1 1 1 I 1 1 I 1 1 1 T -, 1 -, -1 - - -I - - - 1 -- - - - T - - - -__..1___1_- L__...J___---~-_-I___L__...J___--- - L 1 1 I 1 I I 1 1 1 ---I -I---ï---I------ï- -I---r--ï------r- j -I -l -! 1. - I Two Phase Data c : i ~ 1.50 1.30 1 .10 0.90 - ...... Single Phase Data I 5000 5200 5400 ------- 0 2000 4000 Pressure (psia) 6000 8000 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 36 Oilphase-DBR Table 4.2 BP Alaska Recombined Reservoir Fluid Well: NS-08, Field: Alaska North Star Constant Composition Expansion @ 254.5°F Pressure (psia) Liquid Volume % (%) Relative Volume V r=V tolY sat Liquid Density (gIcm3) Compressibility Co (10-4psï1) y. Function Value Psat ( ( ( [ ( ( r ( l ( ( (, ( ( ( ( r ( t ( ( ( ( ( ( ( ( Vr = a+ b exp{-PIc) a= 0.87904361 b= 0.66593913 c= 2865,8933 V-Function is only valid for Pressures < Psat Equations for the Relative Volume and Fluid Compressibility are only valid for Pressures> Psat P - psia Psat - P Y = P(VNsat - 1) Co= - d(ln Vr) dP Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 37 Oilphase-DBR CD 2.50 E ::s Õ 2.30 > CD > .. 2.10 CG ãi a:: 1.90 Figure 4.2 BP Alaska Recombined Reservoir Fluid Well: NS-QS, Field: Alaska North Star Constant Composition Expansion @ 254.5°F 3.50 -~_.~~ r--~-;-~-;---:-~-:-~-I-~-:-~-~~-~~-~ '-~-'-~-I-~-I-~-:-~ j -r-I-,-r-Î- -...., - - -1- t- - - +- -1- +- -1- - -1- + -1- --J~--J~L -L-I-~-I--- ~~,-1.05 _..J- ~_L L_I_L_I___I_-L_I- 1 I, 1 1 1 1 1 1 I I [I I I I I ' --I---I-~- ï ï --I-ï-- - -I - ;- -I - I - f T -I - - - I - I --,-r-,-r- r-I-r-I---I-T-- --j-~-i-t-- t- T --I--t-¡- 1 I 1 1 1 1 1 1 1 -.J :..--1 i.- - 1- - I - - - 1- .../. = j = ~ j = ~ = = =:= t =:= = =:= i -'-1.00 1 'I 1 1 1 1 1 1 --1-;--1-;---1 -I-T-I---I-ï I I ! I ¡ I I - --, -:- -¡ -:- - - ï 1- ì -1- - -1- Î -¡- - -1- ¡- -J - ~ - - t- 1- t- -1-- -1- + -:- - -< -.. -< -.. - - -L 1- -L -1- - -1-.. _1- - -l- L- -.J - ~ - - L 1- 1- _1- - _1- -1 -'- , I I I I t I I I - -: - ~ -: - ~ - - ~ - - T - -:-. + - ~- 0.95 --'-¡-I-ï--r- T-I---I-\-I- - -, - 1-'- r - - í -I T -1- - -1- T - 1- -..,-:-....,-t'"'--t-- -r-I--- --t-,- I I I I I I I I I I I I I I I I I I ¡ I 1 I I I I I I - -I - I- -J - ~ - - J,.. -I . ... -1- - -1- .J. - i- -L - - ~ - 1- ..J - ~ - - I- -J - L -I - - -Î - J,.. -, - J- - - ..J.. -1- ~ -1- - 1- J - ~ -I - - -.J - - -.J - L - - L _I - 1. _I - - ~ 1 - l - - l - - .J -- 1- J - L - L -.J L - - -' - L -' - 1. - l - 1_. l - 1- - 1- -' 1- -J.- - _I - ~ _I - - - - .L 1 1 1 - - .J - 1- J - 1- - L _I - L. _I - - _I - 1.. _I - 1. - - 1 l - 1- .J - J- I 1 I 1 1 I 1 1 1 1 I 1 1 I 1 r I 1 1 1 I 1 - -I --I -- --, -- ,- " t"l ~ I - 1- I - I~ - - 1- -I - I -, -I - "I - - I I" ~ 1- I I 1 I 1 I 1 I 1 J 1 I I ¡II I 1 : 1 1 1 1 I 1 1 I - '1 - ,.- '[ - r - - í -I - - ¡ - - -I - T T - - ï - 1- ì - r - - í ì - r -: - - -I -. r -: - T - - T - 1- ì - t -- -t - 1- ~ - 1- 1 - - -1 - !- -1 - r - - 1- -1- -1- - -1- "'t -!- .,. - - -t - t- -t - t- - - r- ..., - t- -, - - -I - 1- -! - t- - - T -1- .,. -1- ~ - 1- -- - ¡- -- - - ~ - - -j f- - - f--I- f- 1-, - .. -1- .. - - -! - 1- -I -- f-- - - f- -j - I- -I - -I - f- -' -- + -+ + -1- -+ - 1- -I - 1- -! - - .....J - L -! - L - - .J... _I_.J... 1- - -1- ..I.. _1- -1. - - ...1 - 1- .J - L - - L -! - L -I - - _: - .J... _: - 1.. - - l.. -1- ..l -1- ~ - 1- ..;. - L .J - 1 1 1 1 I 1 1 I 1 1 I 1 1 1 1 1 1 1 1 I 1 I' 1 1 I 1 I 1 1 I 1 I 1 1 I 1 1 1 1 I I I --~----¡ ~ -- ~--~--~-I-~- --~--T ~ -I---I-~- -I - I I - ~ - I - - I - I-I ~ T - I I - 1- 1- I --I - -I r í - T - - I 1-1 ~ I~ - - I ~I ~ r -, - - T -, - T- - T -1- T 1 i - 1- -, 1-1- - ï - :- -I í T '-1 - i - ,- i - -r 1- ì -~ r- -- r I r r -I T - T -1- i - 1- """T .- 1- -, - r-Î - I I 1 1 1 1 I I I I 1 1 1 I [ 1 1 I I: J 1 : I 1 I - --I - ~ --j - t- - - +- -1- +- -I - -1- -+ _1- -t. - - -+ - ~ .....¡ - ¡.... - - \- --i - I- -I - - -' - +- -, - +- - - -+- -1- ..... -1- -+ - 1- ....;. - ~ -I - _..J - _I --, ,'- - - L _I - ,L _I - - 1 1. - -.l -- L- J L. _J - l -. - -' - L -- 1. - L_- 1- J. -- I - - 1- - - 1- ..J _-! L_I _1_1_1_1- _'_1 _1 _J-I_J_I___L_'_L __'_1__L__1_1_1_1- _1_-,_1_..1- I! 1 1 1 ¡ 1 1 1 1 1 I I I I 1 1 1 1 1 1 - -I - -I - I -I - 'I I ï - I ¡- I - 1-' - I- 1 ¡ - - "I - - I" I 1 - 1- - - 1- I - = ~ = = ~ = = = = ~ =: = ~ =¡ = f _:= ~ = = i = = ~ = := ~ = t J = ~ j = : - = = = = ~ =' - ~ = = 1 =:= ~ =!= =:= - = ~= : = - .....J - - -: - - - - .J... -1- .J... -1- - -I J.. - '- 4. ....J. - I- -I - \- -' - I-- ---J - I- -; - - -: - .J... -: - .. ... - - .. ... -1- -i- - t- - 1- ..J. - I- .... - 1 1 1 1 1 1 1 I I I' ,u- - ~ - - =: = ~ = = t =:= t _1- - _1- - = i - - j =:= j =:= = - C =: - C - = = ~ Psat = 4885 psia t I 1 1 J 1 I 1 I ; I 1 1 1 1 I I I J I I I I - -I - - -I - - - - "I -I - T - - I - 1- ï - !- - - 1- -I - I -¡ - -;-¡ - T -; - ï - - ï -1- ï -1- - 1- ~ - 1- ï - I - - -I - - ~ - T -I T - "1 -'"1 [' r- -I 1- - --, - r '--I r T '-I'--r 1-- 1- -l 1 1 1 1 1 I 1 1 I 1 1 1 1 1 1 I ,I I 1 - ~ - - - - - - - f- -1- ~ -I - - ; ~ ~ ~ = ~ ~ = t j = ~ = ~ = ~ ~ t ~ = f = = ~ -1- ~ =:= 1 ~!~ ~ = ~ j = J I Iii I : 1 1 1 I I 1 I 1 Iii I 1 ......'-_u- 1 I I I I - -[ - ;- -I - ;- - - f - i - T - I - - -; - T - - 1 - - ï - 1- ï - 1- - - I - - - - - - f - - T - - T - 1- -:- - 1- - ,- - - 1- ï - -I - í --I T - 1 - - T - -- ì 1- 1 - I - - r I í T , -- I ï 1 ... I~ - 1'- "1 ---j----t--.....- r-!---;---I---I--t----t---t'--i--1-¡---r---t ¡- -t I.,. 1 ï 1---1--1- +-,-1 - +- I I t + -. - -I - ¡..- 1 j , 1-- -, I--J 3.30 *;:~œ ~ 3.10 2.90 2.70 Single Phase Data I 4000 4500 5000 5500 - 1.70 1.50 1.30 1.10 0.90 0 1000 3000 4000 5000 Pressure (psia) 7000 8000 2000 6000 Oilphase-DBR Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 38 Table 4.3 BP Alaska Recombined Reservoir Fluid Well: NS-15, Field: Alaska North Star Constant Composition Expansion @ 254.5°F Pressure (psia) Liquid Volume % (%) Relative Volume V ,=V tolY sat Liquid Density (gIcm3) Compressibility Co (10"psï1) y- Function Value ,:::;"",', : Psat ( ( Vr = a+ b exp(-P/c) a= 0.89097759 b= 0.5691499 c= 2805.7273 V-Function is only valid for Pressures < Psat Equations for the Relative Volume and Fluid Compressibility are only valid for Pressures> Psat P - psia Psat - P Y = P(VNsat - 1) Co= - d(In Vr) dP ( [ ( ( ( t. ( l ~ ( Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 39 Oilphase-DBR CD E ::J Õ > CD > ~ ftS "i a:: Figure 4.3 BP Alaska Recombined Reservoir Fluid Well: NS-15, Field: Alaska North Star Constant Composition Expansion @ 254.5°F 2.30 I I : -:- ~ -:- 1.05 -1- + -I- I I I + 1 1 1 -1-+-1- 1 I I I I I I I I _I_i_I- I I I 1.00 I I I I I I I 1 I 2.10 I I t I I I I - Î - [ -I - I - -I -. I '-1- I I I I I I I - ~ - t- -1- t- - - t- -1- +- -I- I I I I I I I I ---1,-~,-1 1----+--1-+-1- I I I I I I I I - ~ - I- --' - I- - - I- - -I- I I I I I I I I I I I I I I I - -.! - L _I .- L - - L _I - I I I I I I -,_,_!__l_~ l..._I- _I- I I I I I I I I , I I I I I I I - - - I -I - I - - I -I - I I- I 'I I I I I I -I - I - - I -I - T I- I I I I I I I I I I I I I I I I 1 I I I I - ...., - ï -I - ï - - ï -I - T - - I I I I I I - 1 - - -"I - 1-- ~ - t- --I - t- -I I I I I I I - --1 - I- -I - I- - +- -I - f. -I I I I I I I I I 4500 I Two Phase Data ~ I I I I I -I-ï-I- I I 1 -1- T -I- I I I I I I I I I -:- ~ -:- 0.95 Single Phase Data I 1.90 1.70 -1- .t I I I -1- + -I- I I I 1 I I I I I I I I I I I I I I I I -1- ..J. -1- ..J. - - J - I- ...1 - ~ - - -- ..... - J- -I - - -1- .t. -1- .J.. -L. - '- -1- -1- - - 1- ...l - I- ~ - I 1 I I I I I I 'I 1 I 1 1 I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I - -.! - L _I - L - - L _1- 1 _1- _1- J. _1- 1 - J -- 1- .J - L - - L -.J - L .J ,- - _1- 1 _1- 1. 1 _,- 1 _1- - _1- J - 1- ~ - I I I I I I I I I I I I I I I I I I I I I I I I I I I I - _I - ~ _I - !... - - 1. _1- l 1- ..!.. 1 -- - J - 1- ...! - '- - - - _I - _I - - _I - .!.. _1- 1 - ,- J.. - '- 1 _1- - - 1- ...! - 1- - - I I I I I I I ¡ t I ! I I J I I ¡ I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I - - - I -I - I - I I I - 'I I' ~ I I-I - ~ - -I -- - -I -I - I 1- - ~ 1- I - 1- - - I I I I I I I I I I I I I I I I I - I -I ~ I - - I T - - T I ~ -I I I ~ -I - I -I - 1- - 1- -- I- I I 1 I I I I J I I I 1 I 1 I I I I I I I I I I I 1 I I I I I i I I j I 1 I I, I I I' 1 ~:~-:~:~:Jt~~~L~~~ : ~-:-i~~L:-:-'~ "~ --:---:~:-:: -:-- T-:-~~:~:-~ 1 I 1 I t I : 1 1 1 1 I, I 1 I 1 I I I I 1 I --';-1--1-+---+--1-+--1-"';"-1--+ -'--1---1-- +--1-+ +--"¡'-I---I-~-~"""- I I 1 I I - 1.-- - -- 1-. -I - -L -I ~ --I l I -- --I- I I I 1 I 5000 5500 4000 I I 1.50 L -I I I 1.30 , I I 1 I I I 1 I 1 1 1 - J - 1_- .J - '- - - _I - L _! - - _I - 1.. _1- 1 I 1 1 'I 1 I 1 , ~ ~ :~ t ~ ~ ~ ~ -: Psat = 4640 psia [ 1 : I' : I 1 : I I I : : : ï - ;- - - ~ -I - 7""" -I - - - 1- T -I - T - - I -,- ¡ -1- 1 - 1- ï - 1- - - 1 I I 1 I I 1 I 1 I I 1 I I r I I I 1 I 1 1 1 I 1 --I-r-:-T î-!-ì-I-- 1-' r~- 1 1 I 1 I 1 1 1 I 1 - - -I - T -I - T -! - "t" - - Î -!- - - ¡- "1 - r- 1 1 1 1 1 1 + 1.10 I I , _-,_L_'_L L_'_l_'- I 1 1 I I 1 1 I _I - !- - - ~ l - I -- I I 1 1 I I I 1 1 1 ---ï-I-ï--, ï , I 1 1 1 1 - - - ¡ -I - ï - - T ï I I 1 I I 1 I 1 1 I I I I 1 1 I I I I 1 1 1 - - - r -I - r -, - ! -I - r -1- .l. ì - - ì - r ì - .- 1 I 1 I Iii I I ,: 1 I 1 - - - r -I - r - - r -I - "t -1- - -1- -r - i- î - - "1 -:- "1 - :- - - ¡ I I' 1 1 1 1 1 1 tit -t 1- --I - : 1 I, 1 1 1 1 1 1 I I ---I--I-I---..L-I-+-I- -1--+-1--+- -!.-I-.J.----:""'-I-;,...-i- 1 ' 1 I 1 1 I 1 . I I I 1 I 1 I I 1 I .1 - ,- 1 _1- ,- - 1- J - 1- -.: - I I I I I I I 0.90 0 1000 3000 4000 5000 Pressure (psia) 8000 6000 7000 2000 Oilphase-DBR Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 40 Table 4.4 BP Alaska Recombined Reservoir Fluid, N5-0S, 5100 psia Psat Five-Stage Separator Test PROPERTY STAGE .1 STAGE #12 STAGE tI3 STAGE N STAGE tIS STAGE 16 Vap. Den (gIcm~) 0.044 0.020 0.006 0.003 0.000 ,,:;uq:~=:,,~:.,~. ,.:,:::;-,:,;:~t~,f:;:"~~'~ ¿~,<,';_c~':~:'~~"'1F:'!-':'(!T> '-~:';S>¿;ï1~7>fY ::r'~~:\~m~::~i':', :~:<. '%~';:"" ~,.' '-:, ',::,: ~,.,::,~~i;.""~ :'.;~: '{'i.'~:¡;r ;,;~; ;~.-,!:, ,',:;;'ojjt;¡::;"j~.;;:;,!f;' ~>!'.~"~~'.2bö:¡;':'~;':;,;;i '!';;,'i¡';5ì);"\;-;:'" .:i", ::, "o:ool'r ' , 'vàp HeatVal"- ", .' 1159' ',' - " 1242:" ,"'! "1815'" " 2788' ' .0 GOR 1650 106 103 59 0 ~:Y:f~~t~~~~t~~~ ~¥t~~lf~~~?l~1rrq~,~~?D:tt{~jn~~~f~;~~1 ~~~~~~~fj~~~~,~~~~r..'~?t~~f~~f;~~¡~~.'~ '.~~:?P~~;f,:'~~:.:F~;:;:;:¡~:~{ i~::~~:.Y~:~~;;.:lir~t~ef~ . 'I'" ,.". .-,";. a) Calculated, at 6O'F (81",1) b) Calculated, Dry basis BTU/set c) set gasIbbI of 011 at STD conditions d) set gaslbbl of 011 at separator conditions e) fluid volume at sep conditionslfluid volume at STD conditi0n8 Residual 011 density at standard conditions 0.821 glcm3 Sep gas gravity (average) S. .. [IR¡*SIIIŒR¡] Where: R; GOR (set gaslbbl of oil at sm conditions), j: separator stages 0.815 Sep gas heating value (average) Lo . [IR¡*Lo¡I:R¡] Where: R; GOR (set gaslbbl of oil at sm conditions), j: separator stages 1239 BTUlscf (dry basis) Shrinkage FVF r ( From first to second Sep conditions 0,943 1.060 f:l'iJl,~ijj;tj;,tbjiÎtIDI,~'t.I~::;jD'112,J~:;f.(:U;;.;¡t:1,;:;': ,::::i;;':j~:':;í~j;~;:;i&;,/::::L~,,:>:e.:}!;;;t:fg!;~t':: ,,~,':,:,,:::\ :};;;:;:~;;'>}xf;;¥i ;;~>f:::':,:¿',;9'_"';:): " ':: i:i:,i'f~it¡~Y ~~~_~Jr¡'~I~_~~;;éà;i;;';i\:2J;i:¿ ";'i;(;,;:;:j;};~\::i:,;1ti~t~èh~;;;;;;;""k;;':.;¿,''::"". ,;:~;~;E:'è~:i'I::;~'.,:.,,:ú,:,/~}~b;5ft. ::1£<.{¿g;;" "".;: :,;:,;:<;/.;1;.;;:, From fifth to sixth Sep conditions liF'~øJ:a,.""Q lAiW.:.';'j t r ( ( ( ( ( ( ( ( ( ( ( ( ( l ( ( ( ( ( ( a) set gaslbbl of condensate at STD conditions b) Fluid volume at Psat & TreslFluid volume at sm (.1("'1.~.J;1f;1C.]......)'I'gl.n":¡ Pressure - psia Temperature - F Stage 1 750 160 Stage 2 325 157 Stage 3 70 157 Stage 4 20 157 Stage 5 15 60 Stage 6 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 41 Oilphase-DBR Table 4.5 BP Alaska Recombined Reservoir Fluid, NS-09, 5100 psia Psat Five-Stage Separator Test Vapor Composition 1st Stage 2nd Stage 3rd Stage mole % 4th Stage 5th Stage COMPONENT MW ~',;.:~0t -'fl:: ~ , '~. Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 42 Oilphase-DBR Table 4.5 Confd SP Alaska Recombined Reservoir Fluid, NS-09, 5100 psi a Psat Five-Stage Separator Test Vapor & Residual Liquid Composition 6th Stage Vapor Residual Uquid COMPONENT MW mole"!. ~ .;.;::.;r~~..:,; .~: . ,....-~>~j/~,~.:~~~,:~'" :,~:. -~ I.~:~ : r r r [ ( ( r ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( oc .~ OC ~9 402.00 0.6? Oilphase-DBR FilE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 43 Oilphase-DBR Table 4.6 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13 , 4850 psia Psat CONSTANT COMPOSITION EXPANSION @ Tres (254.5°F) Pressure (psia) Liquid Volume % (%) Relative Volume Vr=VtolVut Liquid Density (g/cm3) Compressibility Co (10"psï1) y- Function Value Psat :';";''!';':';:.;1'Øäcf'':~::;''Y,'1'"'-;?!,è¡;~;1ö«:.~'1j,'f4.~f :,i';F2C~,,(";ô?~:,¡~, '. ~ :i:"',:,,1i':~: '- . ,;=,c1g;$:J';"'-c;:~ 6500 100.000 0.953 0.564 22.5 , .. ,-~ØöOõ' w"ii:,:'~ii':'" "~,,,Jj',,-"'"'~:,~.ö_'" ,:" \"-'.~"¿:'ö~'55t,,~~A- ,'- '~'~;$2'~':~_f/~'~ ,- 5500 100.000 0,978 0,549 30,5 :'~~'- :'l;6ölØQj"Y":!';:,Yi' ):jéØ. - '.iJ:S4è ' .,' , I'\.~I:,,(':',I'" 4855 100.000 1.000 0.538 36.9 . :c::.:g¡~ . , : ,ilt.,}t!,:,-'..- . ",,-.1.ÖØ6 : :' ';;i,{,;-~" ' Ì;1JJJ. 4530 .86:,~71 ;,. ,.1,026 2]51:, " ':,~~~ ," ,'1: '. s.~", "c', . ,'.,',',:.'"'044,, . ;2.~;",: 4034 73.426 1.078 2,603 j~,:;ðk~i%~~¥}h~t'iÞr~f~t!&_~~1t~t*i:~~i:~"%~~1~ti~:~~ ~~t~i%~~;t~;~;'é:;\~.:!g~~:!:5j2i~ @¥jti¡i~~'f~;t~~2'i1~~~Æ~iIfY:8:¡~~~~~;~i:;{X;;;t 1187 21,196 2.829 1.690 Vr = a+ b exp(-P/c) a= 0.88992846 b= 0,58080472 c= 2926.866 V-Function is only valid for Pressures < Psat Equations for the Relative Volume and Fluid Compressibility are only valid for Pressures> Psat P - psia Psat - P Y = P(VNsat - 1) Co= - d(ln Vr) dP Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 44 Oilphase-DBR ( ( ( ( ( ( ( ( ( ( ( " ( ( l ( '- (. " ( ( ( ~ 2.30 ::s Õ > CI) > o:¡:¡ ca ë& 0::: 1 .80 Figure 4.4 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13 , 4850 psia Psat CONSTANT COMPOSITION EXPANSION @ Tres (254.5°F) 3.30 1.30 I I I I I I --:-~-:-~--~-:-~-:-- I ~-:~1.05 - I I I I I I I I I J : I I I I I I I I I I 1.04 = --I-ï-I-ï--'-I-'-I-- 1-1- : I I I I I I I I I 1.03 = I I I I I I I I I I : --I-ï-: ï--'-I-'-'-- 1-1-1.02- ! I I I I I I I I ¡ I -,}_!-_'-!-__!-_I_.!.. --,_.2. 1.01- , I 'I I" I I - : : :: :::::: 1.00 ~ : : :: I::: ::: 0.99 : -~-~-:-~--~ :-~-:---:-f-:-0.98 ~ -~-~_:_~--~ :_~_:_--:_~_:_0.97 ~ : : :: : :: ::: 0.96 ~ -~-~-:-~--~-: ~-:---:-~-:-0.95 : , I I I I I I I I I I I _-l_L-I-L_-L-1 L-I--.-I--'-I- I I I I I I ¡ I! I I I I I I I I I I I I I I I I I I I I I I I I I I \ I I I I I! I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I, I 'I I I --<-1--1-1- ,1---1-1---1---1--+-1-+---11--<-1---1--1-1--1 --1-1---1--1----1--1,--1- - 1--1--1--<- I I I I 1 I I I I I I I I I I I I I I I I I I I I I I 1 I I 1 I I I I I I I I I I I I I I I 1 I I I I I I I I I I I I 1 I I I I - -i - I- -I - I- - - +- -1- +- 1- - -1- + -1- + - - + - I- -I - I- - - I- -1 - I- -I - - -I - +- -1- + - - + -1- + - 1- - - 1- -I - I- -I - I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I 1 I I I I I I I I I I I I I 1 I I I I I I I I I 1 I --I - I- -I I- - - +- -1- +- -I - -1- + --1-' + - - -1 - 1- -I - I- - I- -i - I- -I - - -1- +- -1- + - ,- +-1- + -1- - - 1- ~ - I- -! - I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I I I I I I I I I I 1 - -j - r -I - r - - t- -1- t- -I - -1- ;- -1- -¡ - - '1 - ¡- '1 - ¡- - - ¡- -j - r -I - - -1- t- -1- T - - T -1- ;- -1- - - 1- '1 - r -j - I I I I I I I I I I I I 1 I I I I I I I I I I I I I I I 1 1 I 1 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ¡ I I I I I ! I I I 1 I I I r I I! I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I - -, - r -, - r - - r -1- r -1- - 1- T -1- , - - , - r -, - r - - r -, - r -, - - -1- r -1- T - - T -1- T -1- - - 1- -, - r -, - I I I I I I I I I I I I I I I I I' I I I I I I I I I 1 'I I I I I 1 I I I I I I I I I I I' I I I I I I I I I 1 I I I I I I - -, - í -I - í - r T -1- - - T -1- T - ì - 1- -, - í - - í -I - í -I ,- - -1- í -1- í - - T -1- T - 1-- - -- 1- ì - 1- I - I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I - -I - ï -I - ï - - , -1- , -1- - -1- 1 - - ï - 1- I - 1- - - ï -I - ï -I - - -1- , -1- T - - T -1- 1 -1- - ï - 1- I - I I I I I I I' I I 1 I I I I I I I I I I I I I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I 1 I 1 I I I - -I - ï -1- ï - - T -1- T -1- - -[-I - ï - - ï -1- ï - 1- - - ï -[ - ï -1- - -1- T -1- ï - - ï -1-"1 -1- - - j- ï -1- ï- I I I I I I I I I I I I I I I I I I I II Psat = 4855 pSI.a LI I I I I I I I I I' I I I I I I I I I 1 I I I I I I I I I I I 1 I I 1 I I I I I I "",." I 1"'-'- I 1 1 I I I I' I 1 1 I I 1 I I 'I I I I I I I I I I I 'I' I , I I 1 , I I I I I I I I I I 1 I 1 I' I I I I I I I I I I --I-¡--I-ï--1 '-\---I-ï-I-ï--I ---ï--ï- -ï-'---j- I"-I-ï--ï-I-ï-j---¡-ï-I-ï- 1 I I I I I I I I I I I I I ) t I I I I I ¡ I I I I I I I I - _I - !... _J !... - - 1 - - J - 1- J - !... -J !... _I - _I - l 1- - - 1. 1 - - '- J - 1_- ,) 1 I , I I 1 I I I I I I I I I I I I I I I I 1 , I I I I 1 1 I I I I I I I I I I I I I I I I I I I I I I .. .J - L _I - L - - 1.. _1- 1.. _1- - -'- 1 _1- J. - - J. - 1- .J - L - - L .J _1- 1- 1. - - 1. _1- J. _1- - - L .J - 1- .J - I I I I I I I I I I 1 I I I I I I I I I I I I I I I I I 'I I 1 I I I I 1 I I I 1 I I I I I I I I I I I 1 1 _.J L _I - L - - L _1- l _I .1 _1- .1 - - ..1 - 1- I 1- - L.J - L _I - - _I L 1 _1- .1 _1-1- 1_- J 1- J I I I I I I I I I I I I 1 I I I' I I I I 1 I 1 I I I I I I I I I I I I' 'I I I I 1 I I I 1 I I I , I 1 I 1 1 1 1 t I I I : I I I I I I I Two Phase Data 2.80 Single Phase Data I 4000 4500 5000 5500 6000 - 0.80 0 1000 2000 3000 4000 5000 Pressure (psia) 6000 7000 8000 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 45 Oilphase-DBR TABLE 4.7 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat DIFFERENTIAL LIBERATION TEST @ 254.5°F . LIQUID PHASE PROPERTIES GOR Data Pressure Cumulative Produced Solution Gas GOR (psia) GOR1 RS1 (scf/STB) (scf/STB) Calculated Oil Density (g/cm3) liquid Data Oil FVF2 (bbl/STB) Oil Viscosity (cp) Viscosity Ratio Oil/Gas3 . This step was peñonned at room temperature Dead Oil Density at STD Conditions (60°F & 15.0 psia) IGas Volume @ STD I Residual Oil @ STD 280, Reservoir Oil Volume @ P,T per Unit Volume of Residual Oil @ STD 'Gas Viscosity Calculated from Lee at at correlation 0.829 g/cm3; 39.2°API TABLE 4.8 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat DIFFERENTIAL LIBERATION TEST @ 254.5°F . VAPOR PHASE PROPERTIES Pressure (psia) Vapor Density (g/cm3) Vapor MW (g/gmol) Vapor Data Vapor Gravity1 (air=1 ) Z Facto,.z Total Gas Total Two Phase FVF3 FV¡:4 Co (bbl/mm set) (bbl/STB) (10"psr1) Calculated Gas Viscosity6 (cp) . This step was peñonned at room temperature 1 Vapor Phase ~/MW A. 2 Z=PV/nRT 3~, Reservoir Gas Volume @P,T I Gas Volume @ STD 4 Sr. Oil FVF + [(Total liberated gas)' Gas FVF] 5 Co=-1/Bo[(dBJdP)-BG(dRJdP» 6 Lee et ai, Correlation (Lee A., Gonzales M,H" Eakin B.E., JPT. 997-1000, Aug., 1966) Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 46 Oilphase-DBR Figure 4.5 BP Alaska Recombined Reservoir Fluid, NS-Ð9 + NS-13, 4850 psia Psat DIFFERENTIAL LIBERATION TEST @ 254.5°F 3000 r 2500 [ ( ( t ( ( ( ( ( r ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( 2000 m l- t/) ;¡:: CJ t/) - ~ 1500 ca a: Õ t/) ca C) 1000 f I I I i I I I I I I ¡ I I ¡ \ - - -J - - L - - - - - - _: - - ~ - _: - - ~ - - - - ~ - ~ - - ~ - ~ - - - - ~ - _: - - ~ - _: - - - - ~ - - ~ - ~ - - ~ - . I I I I ! I I I I! J I I I I I ! I I I I I I I I I' I I 1] ¡ I I : -- I. I" ! -I i - 1- -- ï 1- - ï -- - ï -1- - ï -1'- - - -- -I - 1- - 1- I" I I t I I I I I I I I r I I I I I ., - )- - - - - - - - -1- +- -I - - t- - - - - t- -: - - 1-. .- -t - + - -1- - +-- - -I - - - - -I -i - 1- - - I I I I I I I I I I I I I I 1 I __~__L______-- _L- _L____L_~__L_~____~- _L_~____~__L_~__L_- I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I -.- Produced ---,- I I I I I I I I I I I I I I -- ~ - ,- - -" - - ,- - - - -:- - ~ - -: - - ~ - -- - ~ - ~ - - ~ -+- Solution - -: - - - - ~ - - ~ - ~ - - I I I, I I I I I I I I I I I I I I I - - ï - - ,- - -; - - - - - -,- - ï - - ï - - - - ï - ï - - ,- - ï - - - - ï - -,- - ï - -, - - - - -, - - ï - ï - ,- - - I I I I I I I I I I I I I I I I I I -I - - 1- - - -1- - +- - -1- -- - - - - I- - -I - - 1- - -I - - - - + - -1- - +- ---1- - -- -I -- I- - -I I- I I I I I I I I I I I I I I I I I __L L- _L__- L_J L 1____1- -L- J L- __L I I I I I I I I I I I ¡ I I I I I I I I I I I I I I I I I , I I I I I I I I I I I I I I - - -' - - ,- - .l - - ,- J.. -- _I --- L - - - L - -' - - 1- - .1 - - - .1 -1- -- J.. -I -- - - ..J - - - -' - -- 1- - - I I I I I I I I I I 1 I I 1 I I I I I I 1 I I I I I I 1 I I ï - ,.,- - -, -- - T - ï - -- - 1- ï - - 1- - I - - - . 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'- - -' - - 1- - 1 - -- - - 1 - _1- - 1 - - - _, - - 1 - -' - - I ¡ II! 1 1 I I] t 1 1 1 1 , I 1 I I 1 1 I I I 1 I 1 , , 1 , I 1 I I , I I , I I 1 I 1 I I I I I I I I 1 1 1 I - - -' - - ,- - .l - -;- 1. - _1- L - - L J - - ,- - .J - - .1 - _1- - 1. - _,,-- -- -- - .J - - L - - - I- I 1 ' I 1 I I 1 1 I I I I 1 " I I 1 I I I 1 I 1 I I I 'I I I I I I 1 - - ï - -- ,-- - -, - T - - ï -. - -- ,- ï -- ,- - 1 - - - - T - -I - -- ï -, - -, -- - ,- -- ï - ,- - - 1 I 1 I I I 1 I I I I 1 1 I I I 1 1 - - -4 - - 1- - -" - ,- - - - -1- - - - - -I - - +- - - - -- I- -- -I - - 1- - -I - - - - + - -1- - - - - -I - - - - -I - - I- - -I - ,- - - I I , ,- " I I I I I I I 1 1 1 1 I - - -' - - -'- - _,- - !.. - ,_- -- _, - -- 1- -- -' - - - - J. - _,- - 1 - - -' - - '- - -' - -- I 1 I I I 1 I 'I I I I I ! ~! ~ ~ ~! !!! !)! 500 0 0 4000 5000 1000 2000 3000 Pressure (psia) Oilphase-DBR Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 47 FIGURE 4.6 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat DIFFERENTIAL LIBERATION TEST @ 254.5°F- LIQUID PHASE PROPERTIES - ('" E .!2 0.80 C) - >- - '~ 0.70 Q) 0 ~ .:; 0.60 CT ~ CD 2.6 ..... en ]5 2.2 a ~ 1.8 LL ð 1.4 0,5 ã: 0.4 ~ ?;o 0.3 '(ñ 8 f/) 0.2 :> ~ .:; 0.1 CT ~ 0.0 0.90 0.50 , - - ,- - - , In, -I - - r , -,- r - , -,- r, - , r , -,- - ~ -, - r r - -,- r , -, - - r -, -,- r - , -,- , -, - - , r l -,- + -, -,- - - -,- r- + -1- - t- -+ -1- r- - -¡ -1- t- -t - - r- t- -¡ -1- - -;- -1- r- +- - -1- r- + -1- - t- - -1- r- - -¡ -1- t- -+ - - r- +- -¡ -1- ~ -¡ - 1-- f- - ..-1- t- + -I - I- -+ -1-- I- -4 -1- - -t f..- ¡... 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Liquidfrom DL Test <'J..l,qìJi4" :f,Í'QmPtï~t1t:>\ " ,ç~- < " Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 50 Oilphase-DBR Figure 4.8 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat OIL VISCOSITY @ Tres (254.5°F) ã: ~ ~ 0.3 ¡ñ 0 Co) fI) :> ~ 0.2 .S cr :J 0.5 - ~ - ~ ~ - ;_1_:- ~ _:- ~ - - ~ _: - ~ ~ - L ~ - ~ ~ _:- - -:- '" -- ~ - - ~ _: - ~ ~ - I ~ - ~ ~ - ~ ~ -;- ~ _:- ~ ~ -: - - _: -l-J - ~ ~ - ~ - I I I ¡ 1 I ¡ I I I I L I I (I I 1 I i I I r I I I I I I I I I ~ I I I I = ~ = ~ ~ =:= - =: = ~ -I - ~ = = ~ -I - : ~ = - ~ = ~ ~ = := = =:= = = = ~ = = ~ =: = ~ ~ = = ~ = = ~ = ~ = =:= ~ - 1- ~ - - ~ =: = = -I - L ~ = ~ ~ = = ~ - ~ - :- ~ -:- ,:- ~ -: - ~ -1- ~ -: - ~ -: - - ~ - ~ ~ - :- - -:- ~ -- ~ - - ~ -: - ~ -: - - ~ - ~ ~ - :- - -:- ~ -:- ~ - - ~ -: - - -: - - -: - ~ ~ - :- - 0.4 - ~ - :- ~ 1 -- :~- ~-- ~-: ~ ~ -- -, ~ ~ ~ :- - ' ~ -- ~ -- ~ -: - ~ -: .. - ~ - ~ ~ - :-- -:- ~ '~- ~ -: - -: - - ~ - ~~ : I I I_l_;~ I I I I I I I : ¡ I I I I I I I I I I ,I I i, I i - -, ,- - -- ,- I -,- ï - - ï -, - - -, - ,- ï - ,- - ~ -,- ï - - ï ï - - -, - ,- ï - ,- - - ,- I I - - ï - -, - - -, - ï -, ,- -¡--r-r-I---¡--T-¡-T---r -r-ì--ï-rì-¡---¡--:--,:-T--r-I-r-,- ï--rì!- -I-T-I-T--r-I-"--I -i-r""""1--;- - ~ L.J -1- ~ ~I- ..1. _1- -L L~I-~ L - - -1 - L -.J - 1- .- - t_- .J- -'- -L - - L _1- L --J - - -.J - L --1 - 1- - _1- ..l 1- - - 1. _1- ~ -I - -1 - L --! 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I I I -,-,-, --'-I-,-T--I-'-'-'--'-'-' 1-- 1-'-1- ï ,-,---,-,- -'---'-1 ï--ï-,-,-,---, -,- - --t - r- --t - 1- - - 1- T + - - 1- -I - ¡- --j - - --j - ¡- --t - 1- - - 1- .,. - ,- + - 1- -I - t- -I - - --j -- r- --t - 1- - - 1- T - 1- + - 1- -I ,- j- -I - - -J - r- ---j- r - 0.0 I I I I I I I I 1 I " '1 I I "" 1 I I I I I 1 1 1 1 I I " i' I 1 I I 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 Pressure (psia) 0.1 ( L [ ( ( [ ( ( ( r ( ( ( ( ( ( ( ( ( f ( ( ( Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 51 Oilphase-DBR Table 4.10 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat DIFFERENTIAL LIBERATION TEST @ 254.5°F Produced Vapor Composition 1st Stage 2nd Stage 3rd Stage mole 'Yo COMPONENT MW C~MWt ',28::9 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 52 4th Stage 5th Stage 26~6 Oilphase-DBR Table 4.10 (Continued) BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psla Psat DIFFERENTIAL LIBERATION TEST @ 254.5°F Produced Vapor & Residual 011 Compositions COMPONENT MW 6th Stage mole%. 7th Stage Residual Liquid mole 0/0 t ( ( ( ( ( ( r ( r L, Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 53 Oilphase-DBR Table 4.11 BP Alaska RecombIned ReservoIr FluId, NS-09 + NS-13, 4850 psla Psat Flve-Stage Separator Test PROPERTY STAGE #1 STAGE #2 STAGE #3 STAGE #4 STAGE #5 a) Calculated, at 60DF (air=1) b) Calculated, Dry basis BTU/scf c) set gaslbbl of oil at STD conditions d) set gaslbbl of oil at separator conditions e) fluid volume at sap conditionsllluld volume at STD conditions Residual oil density at standard conditions Sep gas gravity (average) S. . [I:R¡*S ŒR ) Where: R: GOR (set gaslbbl of oil at STD conditions), j: separator stages Sep gas heating value (average) L.. = [I:R¡*L,,¡ŒR¡] Where: R: GOR (set gaslbbl of 011 at STD conditions), j: separator stages From Psat & Tres to first Sep conditions From first to second Sep conditions From second to third Sep conditions From third to fourth Sep conditions From fourth to fifth Sep conditions From fifth to sixth Sep conditions ~::I~':Ji~ (.J:~"'III~I~¡r~':¥ a) set gaslbbl of condensate at STD conditions b) Fluid volume at Psat & TreslFluid volume at STD 1[.1(~"1;1.r.;'II:IC'J-......nl'rl'Jit: Pressure - psia Temperature - F Stage 1 750 160 Stage 3 70 157 Stage 2 325 157 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 54 0.817 g/cm~ 0.823 1254 BTU/scf (dry basis) Shrinkage 0.549 0,948 0.951 0,950 0,960 Stage 4 20 157 FVF 1.822 1,055 1.051 1,053 1.042 Stage 5 15 60 STAGE #6 Stage 6 Oilphase-DBR Table 4.12 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psla Psat Flve-Stage Separator Test Vapor Composition 1st Stage 2nd Stage 3rd Stage mole % 4th Stage 5th Stage COMPONENT MW ( ),00 )0 0.00 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 55 Oilphase-DBR Table 4.12 Continued BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psla Psat Flve-Stage Separator Test Vapor & Residual Liquid Composition 6th Stage Vapor Residual Liquid COMPONENT MW mole % :8 ) CYCL.( NICYCL. :6 ( 8 0,00 ~D- ¥VI 1:..1: C21 '" ' ~~f~~_:,ù "~::: "~.' ~~ Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 56 Oilphase-DBR TABLE 4.13 8P Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat Separator Corrected GOR and FVF Pressure Measured GOR (Rs) Corrected GOR (Rs)1 Measured FVF (80) Corrected FVF (80)2 (psia) (scflbbl) (scflbbl) ',^ Two Phase Data , "PUt:,:,~,~ :~~..::" 4700 '44QQ:',"';,X, '~:~ ;<: "~;\'U;,:, 2500 ,JM>P ," ',' /~,..:,','^ ' "l'::;:~~::';',;" 1514 :<~?~~:j~ , 794 ,;-;:';~'<:4$'~:>.;, : ,"~ ." } , ' }~~"t " 2,368 " 2.1$2", 1.933 ,;::., ':"llM::'::::" 1,544 ",',: "i'i', '}~~O: ,', ,~.218 :,:,; 2.070 ~;.~:;:, 1.690 ::, ,:~.:\."/t;J1~r" " 1.350 "'1:;1$CI:' -', \'1' ',~,,;. 1807 ',)'4~," 1173 :,:atiij;:{,; 544 , ::î~<';I, " .,', Notes: l ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( 1, R. = R.Sb - (RoOb - R.D)(BoSbl BoOb) 2, Bo = BoO (BoSb I BoOb) WhR. Bo Roo R.s.. R.Db BoD BoSb BoOb - Separator Corrected Solution Gas GOR - Separator Corrected FVF - Gas in Solution at Specified Pressure - Gas in Solution at Saturation by Separator Test - Gas in Solution at Saturation by Differential Liberation - FVF at Specified Pressure - FVF at Saturation from Separator Test - FVF at Saturation from Differential Liberation Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 57 Oilphase-DBR = 2500 .a .a ii:: u ..!. 2000 0:: 0 C) 1500 U) ca C) S 1000 4:i ::s Õ 0 500 - ~ 2.6 - :is :S.. 2.4 ... .s 2.2 u ca &L 2.0 CÞ E ::s ~ c 0 4:i ca E ... 0 &L Figure 4.9 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat Separator Corected GOR AND FVF 3000 I - - - - ..., - - - - - - - - ï - - - - - - - - T - - - - - - - - r - - - - - - - - r - - - - - - - - ï - - - - - - - -1- - - - - ---------------t- -----j- r------- r ---1--- --,- - - - - ..., - - - - - - - - -+ - - - - - - - - + - - - - - - - - t- - - - - - - - - t- - - - - - - - -1- - - - - - - - -1- - - - . -------4- +--------~---- ---~ ---~ 1 , , ----~--------~--------~--------~- -------- ---1-- - 1_- L- -,-----_-1_---- -_1._--,--- L ----~----___-l__--____l________L , 1 1 1 1 1 ----ï--------¡--------ï- ----~--------ï--------ï------ - -- I - T - ----~--------,--------T---- , - - - _1- - - - - _I- - - - __--L__- ----~--- -_--L ____L__- - L - -- - 1- ____I ____I ----'----, , 1 1 1 - - - - - - I - - - - - - - - 1- - - - - - - - -1- - - - - - - - - - - 1- - - - - - - - - 1- - - - - - - - -,- - - - , - 1- - - - - - - - -- 1- -- -, - - - - - - - - - - - r - - - - - - - -1- - - - - - - - -1- - - - , , , r - r - 1- --1- - - - - - - t'" - - - - - - - - r - - - - - - - - 1- - - - - - - - -1- - - - . - - - ~ - - - - - - - - - - -1- - - - , - - - - ~ - - - - - - - - -+- Unadjusted -=--=-=--:- - - -- = = = =: = = = = = = = = ~ ~ = = = = ~ ~ = ~ = = = = = = = = t = = = = = = = = ~~~~!~st~~ - - = = = =:= = = =: - - 1 - - - - - - - L - - - - - - - 1- - - - - - - 1- - - - - - - -' - - - - , I I r I 1 I I I I I - - - -, - - ï - ¡- - - 1-- - - - - - - - - 1- - ------T--------T--------r--------r--------r------- - - - - -, - - - - - - - - I - - - - - - - - T - - - - - - - - ï - - - - - - - - r - - - - - - - -1- - - - - - - - -1- - - - - 0 - - - - - - - - - - - -:- - - - - - - - T - - - - - - - - :- - - - - - -- - '-:- - - - - - - - r-- - - - - - -~- - - - 1000 , , --------- --¡---- T ----:--------ï--------T ----4--------~------- -+-- , 2000 3000 7000 8000 4000 5000 6000 2.8 = = = = ~ = = = = = = - = ~ = = = = = = = - ~ = = = = = = = = =: = - = - t- = = = =: = = = = - = = = =: = = = - - - = = =; = = = = - - - .., -- - - - - - - -, - - - - - - - -I - - - - - - - - -1- - - - -I - - - - - - - -- -1- - - - - - -,- - - - - ~ I - - - - - - - - -I - - - - - - - - -I - - - - - - - - -I - - - - - - - -I - - - - - - - - -¡ - - - - - - - - -1- - - - - - - - -1- - - - - - - - -¡- - - - - - - - -!- - - -- - - - - - - - - = = = :1 = = = = = = = = :1: : - - - - - -1- - - - . - ____1______---'---- ----'----, ----1------- -I-~--- --1----- ====1=========1==== ====,=---' , -----'--------4--------4--------~-- ====J-=======J========J========J== ----~--------~--------~--------~-- =-=-=-=--.J - - - - - - - - _I - - - - - - - - _I - - - - - - - - _1- ----~------ -~ ----- -~ --------1- ====J========J==-=-===J=======-J =-- , , , ----~- -,- -------,-- --==:::¡===----::-:::¡=-=--- -=1======= - === 1 - - - - -, - - - - - - - - 4 - - - - - - - - 4 - - - - - - - -I - - - - -I - - - - - - - - -I - - - - - - - - -, - - - - - - - - - ..J - .- - - - - - - ...J - - - - - - - - ....1 - - - - - - - _I.. - - - ..:... - - - _I - - - - - - - - _I - - - - - - - - _I - - - - - ----~--------~ ------ ~--- ------- - ---=J _=1_-- ::::=1- 1= 1.8 ~ 1 , 1 1 , - - - ::- J = = = = :: :: :: :: J :: - - - - - - , = = = = = = =1 = - - - - - - - ::- = = = = = = =1 = = = = = = = = - - - - --I - - - - - - - - --I - - - - - - - ~ - - - - - - -I - - - - - - - - -I - - - - - - - - -I - - - - - - - - -I - - - - . 1.6 ;;;; ~ ; ; ; ; ; ; ; = ~ - ; ; = = ; ; ; ~ ~ = = = :: = = ; =: = ; ; ; ; ; = ; ;: ~ - + U";a-dJusted = = ;:; = = ; : 1.4 = ~ ~ ~ :::¡ = ~ ~ ~ ~ = ~ = :::¡ = = ~ ~ ~ = = = =1 = ~ ~ ~ ~ ~ ~ ~ _I - ~ ~ = = = = = =: = ---Adjusted:: = =, = :: = = : - - - - - - - - - _I - - - - - - _I - - - -, - - - - ~ - - ----~---- --4-- -----~----- --~--------~-------- ------- 1.2 ~ ~ ~ ~ t; ~ ~ ~ ; ~ ~ ~ j ~ = ~ ; : ~ ~ ~ : ; ~ = ; ~ = = ; ;¡ ~ ~ ~ ; ¡ ~ ~ ; ~¡ ~ ~ ; ; ~ ~ ~ ~ ~: ~ = = = ~ ~ ~ ; -I- ~ ~ = : 1,0 1000 2000 3000 4000 5000 Pressure (psia) 8000 6000 7000 Oilphase-DBR Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 58 TABLE 4.14 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat PVT STUDY SUMMARY DATA Gas-OiI Ratio 1: Type of Liberation Total Solution Gas Stock Tank Oil Gravity (° API) Formation Volume Formation Volume Factor' Factor3 :!'~_.~:t~~~;'~~(t2; .."..:'~~,:.. 'Oifferenïíál'" . . .. Liberation 2515 2.~.~:" .. r., 39.2 2.509 2.537 (1) Gas-Oil Ratio: scf of Gas per bbl 5TO at 60°F (2) Volume of Reservoir Oil @ Pres, Tres per volume 5TO @ 5TD conditions (3) Volume of Reservoir Oil @ Psat, Tres per volume 5TO @ 5TD conditions ( [ C ( ( ( ( ( ( ( ( f ( ( ( ( ( ( ( ( C ( Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 59 Oilphase-DBR ---- - -- --- ------ APPENDIX A SUMMARY OF ODBR SERVICE CAPABILITIES OOBR retains a number of specialized pieces of equipment to complete high pressure and temperature measurements on petroleum fluid systems. In addition, OOBR retains advanced GC-based analytical capabilities for completing hydrocarbon fluid analyses. For detailed compositional work other than GC (e.g. SARA & HTGC), we call on the extensive expertise of the analytic chemistry department of the Alberta Research Council (ARC) in Edmonton. For organic solids (wax and/or asphaltene) stability evaluation in crude oil systems at realistic production conditions of pressure, temperature and/or composition (e.g. lift gas operation), OOBR offers two state of the art techniques, namely a laser-based solids detection system (SOS) and a high pressure microscope (HPM) equipped with cross polars. While the SOS (rated to 15,000 psi and 390°F) is an established near infra-red (NIR) light transmittance method, the HPM (rated to 20,000 psi and 390°F) is a recently developed visual technique which enables direct detection of organic solids onset conditions and, more importantly, makes it possible to monitor the associated morphological changes. A distinguishing feature of the HPM technique is its capability to discern the nature of precipitated solids such as waxes (when viewed under polarized light mode) versus asphaltenes (when viewed under normal light mode). Descriptions of the aforementioned and other key flow assurance techniques, procedures, and typical results are provided below. _!';:f'!~I[.]~~.J:j.I[.]~,.'It.!'~r.'..I:j(;j Upon arrival, a sample bottle is connected to a 20,000 psi pump from the water side to check the opening pressures at room temperature. Next, the sample bottle is heated to Tres, pressurized to at least Pres and allowed to equilibrate under continuous rocking for about five days. This process would help disperse deposited/coagulated asphaltene particles, if any, into solution. Following the sample preparation and conditioning described above, a sample of each equilibrated live fluid is isobarically displaced, one at a time, into a pre-cleaned and evacuated pycnometer for density, GOR, and C30+ compositional analysis using a flash procedure. In this technique, an accurately measured volume of the single-phase fluid is isobarically displaced into a pycnometer where its density and mass are evaluated. The pycnometer is then connected to a GOR single stage flash apparatus where the oil is flashed to ambient pressure and temperature conditions. Next, the evolved gas phase is circulated through the residual liquid for a period of time to achieve equilibrium between phases. Following circulation, the volume of equilibrium vapor and the mass of liquid remaining in the pycnometer are measured. The vapor phase is resolved to C15 by natural gas GC, while the residual liquid is analyzed to C30+. From the measured composition and total mass of each phase, the composition of the original live oil may be calculated by mass balance. ~1::(1I=1~1[.lIJ:l..Dr':I::l~':¥~"I~ A.2;;1 .....PV'TCELL Figure A.1 is a schematic of the ODBR visual PVT Cell. The main body of the cell consists of a Pyrex tube housed inside a steel shell with vertical tempered glass plates to permit visual observation of the internal tube contents. The Pyrex glass tube is 15.2 cm long with an internal diameter of 3.2 cm. This translates into an effective working volume of approximately 120 cm3. A specially designed floating APPENDIX A Oilphase-DBR SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Page A 1 piston (described below) and a magnetically coupled impeller mixer are mounted inside the Pyrex tube to allow for a mercury-free operation. The volume, and hence the pressure of the fluids under investigation, are controlled by a variable volume ODBR displacement pump which allowed for the injection or the removal of the transparent hydraulic fluid. The same transparent displacement fluid is connected to the outer steel shell to maintain a balanced (minimal) differential pressure on the Pyrex tube. Equilibration of the fluid under investigation is achieved by means of a magnetically coupled impeller mixer mounted on the bottom end cap. It should be noted that the bottom end cap is specially designed to achieve two main goals: (i) shield the cell contents from any magnetic effects/flux and (ii) provide for charging and sampling the test fluid. ( ( ( ( ( ( ( ( r ( f ( If PC }\ - - - - - JEFRJ ~ / .;' --- -- -- "'- VISU~ ,. "- Oven Boundaries PVT Cell I I/',,- -. ~- -~- T. -: i-=~! ID,,~,~~~~.J I' /' ~ "\. \. I ,...... .." .- 1" I ~.~ \ I ,11 \ I f~' ~ ~ ~I'IIII \ 00' I þ. , I I .. Piston"'" I' 11°1° ~I I ~J. . ~l: ----- \ 0 Unci ~ , I 'I 0 0 'z,. ,e I y er 0 i) 1...- 7~ ' u--::::' v- - I \' D..~ :....... ~ ~ ~Z~ ~~~ I ,I ¡.....-'.'", I k-' ~ I 'f;. ~~. --....-- I ~ / \ ~,~ '- ~ - '- "'" \ 1: ~ ~~ ------. / L___~_~~J \ " DBR Magnetic \ I ~ Mixer System' / '- " .... /' " -' I - "'./ ..... '" ------..",... Constant Rate JE F RI Pump r.;;;] ~ Pressure I~el Side View of PVT Cell Figure A.1 - Schematic Diagram of ODBR PVT Cell Equipped with SDS The entire PVT cell is mounted on a special bracket, which can be rotated through 360°. Accordingly, the PVT cell can be inverted to sample any liberated gas when/if required (for gas diluent studies, the cell is kept inverted at all times, i.e. the floating piston is positioned on the bottom and the magnetic mixer at the top of the cell). The bracket and PVT cell are housed inside a temperature controlled, forced air circulation oven. The cell temperature is measured with a platinum RTD and is displayed on a digital indicator with an accuracy of 0.2°F or 0.1°C. The cell pressure is monitored with a calibrated digital Heise pressure gauge accurate to :t 0.1 % of full scale. The maximum operating pressure and temperature for this PVT system is 15,000 psia and 392°F, respectively. f' L ( r ( l ( ( ( ( ( A.~~2.""::,Ot)~R.S9IjClS;';petect¡on'$Y$temt(SI)S) The visual ODBR PVT cell described above is equipped with fiber optic light transmission probes (source and detector) to measure the onset of organic solids precipitation (due to temperature, pressure and/or compositional change) concurrently with fluid volumetric data. These fiber optic probes are mounted across the windows of the visual ODBR PVT cell as illustrated schematically in Figure A.1. The visual ODBR PVT cell along with the optical probes and the computerized pump are termed Solids Detection System (SOS). The measurement principle of the SDS is based on the transmittance of a laser light through the test fluid while either the temperature, the pressure or the fluid composition was being changed. The entire system is controlled by a proprietary software package that accomplishes two significant objectives. Firstly, a computerized pump is used to control and maintain the system pressure during isobaric temperature sweeps for wax precipitation experiments, isothermal pressure drop and/or isobaric injections of solvents/titrants for asphaltenes precipitation studies. Secondly, the APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A2 ( software (in real time) records and displays the system temperature, pressure, solvent volume, time, and most importantly, the power of transmitted light (PTL) through the test fluid. ~~~,;'\ØAftlt~8.~~:'~[("~} The standard SOS configuration discussed above has been further improved with the addition of OOBR high-pressure microscopy (HPM) in series. A schematic diagram of the set-up is shown below in Figure A.2. The HPM cell is a small sapphire prototype with variable internal diameter and, in turn, working volume. It is connected to the bottom of the PVT cell inside the same air-bath oven. The total dead volume in the HPM cell, tubing and fittings has been minimized and estimated to be 1 cm3. Video L-JJ Recorder Oven Boundary i------------------~ . . : Iln-line : . . HPM . . . . . . . I . I I . . . . ~ . . n I I r--"-'-1 . . . . . . v u . : 0"0 : I 0 0 . : 0 0 : . 0,0 . ~ : DBR n n : r::::::J I PVT . . Cell . . L---I . Solvent : : Cyli nder L______------------~ ~ Insulated Transfer Lines ~~r 8 Q ~. Storage Cyli nder ~ Q ~. - r- i ...-¡ -; o~ Positive Displacement Pump Figure A.2 - Schematic of the ODBR High Pressure Microscope (HPM) A¡,2,~4I, ...QQEJR....P.ttiç,,'$lze:~.lysls,lPSAJ OOBR retains a particle size analysis (PSA) capability based on proprietary imaging software that operates as a synchronous feature of the HPM system. The system was calibrated using particle standards of varying concentrations and size (1-50 f.lm) as well as micro-scale objectives. The PSA software scans digital HPM photomicrograph images in real time at a high sampling rate and simultaneously discretizes such images within a restricted field of view, on a pixel-by-pixel basis. From these data, histograms of particle size distribution are produced continuously and frequently over the residence time of an experimental sample contained by the HPM cell, thus providing information regarding relative abundance, morphology changes and onset conditions. Figure A.3 exhibits a sample PSA report generated during discrete depressurization of an unstable live oil at reservoir temperature. The reported particle diameter is the diameter of a circle with an area equivalent to the projected area of an asphaltene particle. The number counts are cumulative value obtained from analysis of 20 images at a given pressure. APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A3 r c ( f ( ( ( ( ( '- f ( l ( ( ( ( ( ( ( l ( 10000 1000 -L- 100 ~ 10 ~-;.,,- - 1 i IßlInIUln 10000, 1 000 ~" 100 ~. 10jn.:.n.o ..; 1 .! 1011111111 10000 -, 1000 ( 100 ~ 1~ .-~- -------- - :1 P = 10000 psi I 0-- --- _.__.- .. ,- 1 P = 9000 psi I f P = 8000 psi I ----~-- -- --- -----.- ---- -+- C :J 0 Ü 10000, 1000 100 -k''''''. 10 - ;.n 1; n/1IlI1 n 10oo0¡ 1000 -t - 1 00 1fLinn . 1~ itmmnid1ñF 1OO00r 1000 J 100 i-- -, ' 1 ~tlM .'J1IIn-- 100001' 1 000 ~- 100 ~--,-.- 1~ îfDlln i1IIï1" 10000 1 000 - 1~~ ..=n~:' 10000 1 ~gg ~. 'Ulhiumnnnnnßnn: .. .. 1 ~ - mIIIIIIIßßnmm~nnn' 1000 100 10 1 1000 1~; - - I " '~ L ~iA..n,;,ci. P = 6500 psi j 10000 .",.""'" .,.",.,..n., .," ',' . , 10001,1.""".-."-'.'."--, .'. -.'. .,.'. 100 -+ ." .... ..-,... ... I IIßI1I1ß..nn 1 ~ t, IIHlllßnnllll1Ilm1fll1nñn~nñn- n:~ nn n~n -~- 1 0000 1 1000 ~ "''. 1 00 +. ..nllii~~-- . < - ... . . . 1 ~ i ~ IUUmœmllllllflmnntoon;l1f1n'- n~ . n 1100. n 1 11 21 31 41 51 P = 4000 psi I -'-'-~-~--'-'-'-'--'- nlll1nnn I1{1nnn 61 71 81 91 101 111 121 Size (Jlm) Figure A.3 - Sample PSA Histograms for a Discrete Depressurization Experiment APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM ( Oilphase-DBR Page A4 A.2.5C~bridgè Electrorriagnetic\liscometer(EMV) For viscosity measurements, OOBR retains a Cambridge EMV model SPL440 (See Figure A.4). Such a High Pressure Viscometer is a precision instrument designed to accurately measure the viscosity of petroleum fluids. It was developed in cooperation with Cambridge Applied Systems and capable of continuous operation to 138 MPa (20,000 psi) and 190°C (374°F). The SPL440 system can be configured as a stand-alone system or as an in-line component with the OOBR Visual PVT Phase Behavior system. Performing viscosity measurements over the range of 0.1 to 10,000 cP on very small volumes of fluid makes this instrument an ideal component for petroleum fluid laboratory studies. A number of electronics options are available for operating the SPL440 Viscometer, including the ViscoPr02000, a device that is able to provide unparalleled accuracy over the greatest measurement range. Even with this outstanding degree of precision, accuracy and functionality, the SPL440 Viscometer is still easy to install, operate and service. It has only one moving part, a small magnetic stainless steel piston located inside the sensor that is driven up and down using coils, simplifying installation and servicing. The measurement chamber, connected to both top and bottom system lines, allows for easy introduction, measurement, and removal of a fluid from the Viscometer. Measurement Chamber piston Figure A.4 - Schematic Diagram of Cambridge Electromagnetic Viscometer A.2..6......c;-.ÞQI¡lrv.Vi$çqmeter(CV) OOBR also retains a capillary viscometer (CV) rated to 10000 psi and 374°F. The CV set-up consists two high pressure cylinders (32 ml each) connected to a 1.83 m (6 ft) in length and 0.076 cm (0.03 inches) in diameter capillary coil. A differential pressure transducer is used to monitor the pressure drop across the capillary coil. The fluid sample is pumped from one cylinder to the other through the capillary coii by an opposed pump (See Figure A.5). From the measured fluid flow rate and pressure drop, the viscosity can be determined using the Hagen-Poiseuille relationship for laminar flow in tubes, namely: APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page AS L\p ( 1t r4 '\ L\p Jl=- - =-k Q ,,8L) Q Where Jl is the fluid viscosity, ðp is the pressure drop across the capillary tube of length, L, and a radius r, and Q is the volumetric flow rate. The tube constant k is determined by calibrating the viscometer using standards of known viscosity at test pressures and temperatures. Oven Boundary \. ~-------------------I In-line - 1 Densitometer I 1 :~~~~~~I DP 1 Transducer Tl 1 1 1 AI ...- 1 \jJrn ~ ~ +-Pyrex Tube I / / ,. I ~ - ....-LlqUld Level I 1 I'~ ~ Tapered Piston Vent\Vac. Line 1 1 r~-r~ 1 DBR JEFRI 1 1 Capillary Viscometer 1 I 1 L--.J : ' Sample / DBR JEFRI : Cylinders PVT Cell 1- - - - - - - - - - - - - - - - - - - _I / " Vent\ Vac. Line r,~~- --a= === =n- ~ - DBR JEFRI Sample Cylinder DBR JEFRI Opposed Pump =e==iWP - L --3 I- [ r ( c ( DBR JEFRI Injection Pump Figure A.5 - Schematic of Capillary Viscometer Setup ~¡{.IIt:8.lIJ::~~ r ~~~';~}ii~.Qí~çgmPðí"~ij:"~lJiji¡¡ö:j(~~J The CCE test is initiated by charging a known volume of the equilibrated fluid to the PVT cell at Tres and P res. At these conditions, the fluid density is measured and the initial mass of the fluid in the cell is calculated. Thereafter, the fluid is expanded isothermally to a lower pressure, which is still in the single- phase region. The total system volume is measured after equilibration at this pressure, and this volume is used to calculate the single-phase density at this pressure. This procedure is repeated a number of APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR r Page A6 times until the bubble point pressure is reached. Subsequently, the pressure is reduced further by selected pressure intervals into the two-phase region, and at each pressure point the vapor and liquid phases are equilibrated, phase volumes measured and plotted as a function of pressure. The intersection of the single phase and two-phase lines in the PV plot and the visual observations in the PVT cell are used to define the bubble point. ~~#;;/:;Q~ij~"li~tfc,t~) Following the CCE test, the fluid is pressurized slightly above the measured bubble point pressure and is allowed to equilibrate at such conditions for about one hour. The single-phase fluid is then flashed to the first specified pressure condition of the differential liberation study and equilibrated for at least 30 minutes. Subsequently, the equilibrium vapor and liquid volumes are measured using the cathetometer. A portion of the liberated vapor phase is isobarically displaced into an evacuated pycnometer for gravimetric density determination and compositional analysis. After collection of the vapor phase sample, the remaining portion of the vapor is isobarically displaced from the cell. Next, about 5 to 6 cm3 of the liquid are charged into the Cambridge electromagnetic viscometer for viscosity evaluation. Finally, the remaining liquid volume is measured and subsequently flashed to the next specified pressure condition. This procedure is repeated for a total of the specified pressure steps. k3~3.. ....,":çi;)l1s~ht...V()Jumèt,..OêØletlon'..'(Q\Ø) The CVD test is initiated by charging a known volume of the equilibrated fluid to the PVT cell at Tres and Pres. This volume is important as it is used to establish the reservoir volume to which the PVT cell contents are returned after each depletion step. The CVD test involves reducing the system pressure from Pres to the first specified pressure step at which the fluid is equilibrated. Next, the resulting vapor and liquid volumes are determined. In addition, a portion of the equilibrium vapor is displaced from the top of the PVT cell and analyzed for its C30+ composition and density. Finally, additional vapor is displaced to return the fluid system to the initial single-phase reservoir volume as defined above. The system pressure is then reduced to the next specified depletion pressure step and the above measurements are repeated. In all, measurement procedures are completed at 6 to 10 depletion steps. Ai314>:,..iI".$tågeSeparå~ A known mass of homogenized fluid is transferred into the PVT cell and equilibrated at the bubble point pressure and reservoir temperature. The pressure and temperature are then set to the first specified separator condition and the system is allowed to equilibrate. Subsequently, the equilibrium vapor and liquid volumes are measured using a cathetometer. A metered sample of equilibrium vapor is isobarically displaced into an evacuated pycnometer for gravimetric density determination and compositional analysis. The remaining portion of the vapor phase is then isobarically displaced from the PVT cell. Next, a metered sample of the liquid is isobarically collected into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure. After measuring the remaining liquid volume in the cell, the system conditions are adjusted to the second specified stage. Again the liquid and vapor phase volumes are measured and a sample of each fluid is taken for density determination and compositional analysis. This procedure is repeated a number of times until the last separator stage has been reached. A.3.~"",','VisêosityM~asureníenfpsingEMV The test fluid is charged to the vessel and the piston is surrounded by fluid. Subsequently, the piston is moved inside the vessel by imparting a force on the piston using two electromagnetic coils inside the sensor body. After travelling the length of the test vessel, the piston is returned to its starting location by APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A 7 reversing the magnetic field of the electromagnet. The motion of the piston inside the vessel is impeded by viscous flow around the annulus between the piston and the measurement chamber wall. Viscosity is determined by measuring the piston transit time for a complete cycle of piston movement and comparing this to times obtained using calibrated standards. A.3i6....QI$c:l'ét,lsottl~""'I>.Q~~tt_Q~8øl) After charging the reservoir fluid to the PVT cell at T res and Pres or higher, the SDS components are mounted across the full length PVT cell windows. A reference scan of the light transmittance through the fluid is then performed at the initial system pressure. The pressure of the cell is then lowered isothermally at discrete pressure steps (100 psi) with -5 minutes of equilibration time at each pressure step while the cell contents are mixed continuously and vigorously (-1,400 rpm). The experiment is stopped soon after a sharp and dramatic drop in the power of transmitted light (PTL) is observed. This drop in PTL corresponds to the onset formation of a solid phase and/or gas phase. To this end, it is useful to summarize some of the main factors known to influence the light transmittance (L T): . L T is inversely proportional to density; hence, if the density decreases then L T increases. Density is proportional to pressure (above bubble point); hence, if the pressure decreases then PTL increases. L T is inversely proportional to particle size (PS); hence, if the PS increases then L T decreases. L T is inversely proportional to the nucleation density of solids (NDS); hence, if the NDS increases then the L T decreases. . . r ( r r It is also useful to present and describe (qualitatively) typical SDS de-pressurization traces measured for two low content asphaltenic crude oils with (OIL 2) and without (OIL 1) asphaltene precipitation problems at respective reservoir temperatures. These are depicted as Figure A.6 for ease of comparison [Hammami et al., Energy & Fuels 14 (2000) 14-18]. ( ( In the case of OIL 1, the power of transmitted light (PTL) increases more or less linearly as the pressure is decreased isothermally from 62 MPa to 34 MPa. This is likely due to the decrease in fluid density with decreasing pressure within this pressure range. At about 34 MPa, the PTL signal drops dramatically to noise level. This drop is visually confirmed to correspond to the formation of a vapor phase (Le., bubble point is reached). The emerging liquid-gas interfaces cause instantaneous and significant scattering of the laser light at and below 34 MPa. With the removal of the liberated vapor phase below the bubble point, the PTL signal through the liquid phase decreases nearly linearly as the pressure is depleted to about 2 MPa. This is plausible because with decreasing pressure, the residual oil density increases as the dissolved light ends continue to evaporate. ( In the case of OIL 2, on the other hand, the PTL signal increases linearly from 62 MPa to an intermediate pressure of about 50 MPa. With further reduction in pressure, the PTL curve exhibits a plateau (initially) and then commences to decrease gradually and progressively. At about 39 MPa, a vapor phase starts to emerge (Le., bubble point is reached) and, in turn, the PTL signal drops to noise level. The point of departure of the PTL curve from the linear behavior at approximately 50 MPa is interpreted as the onset of asphaltene precipitation for this oil. Below the bubble point, the PTL curve decreases (initially), but then starts to level off at about 24 MPa. The observed break in the curve is likely the net effect of two competing processes. Opposing one another are the effect of liquid density, which increases with decreasing pressure, and the effect of asphaltene re-dissolution, which also increases with decreasing pressure. Accordingly, the increase in liquid density causes the PTL to decrease, whereas, the simultaneous decrease in size and/or amount of precipitated asphaltenes tends to increase the PTL. APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A8 -- ~ .'1:: = ~ ~ ... e .... :s ... S b ~ d: ... i .;¡ _OIL 1 @ 80.6 C) ---OIL 2 @ 68.3 C) I As¡i1akene Onset { ~ 50.4 MPa I , I I I I "If Bubble Point ~,,"-I I,~IIII'I I I I I I I I , I I I I , I , I I 0 10 20 30 40 50 60 70 Press ore (MPa) Figure A.6 - SDS Depressurization Traces of Live Oils With & Without Asphaltene Instability [Hammami et al.. Energy & Fuels 14 (2000) 14-18] Figure A.7 depicts an SDS depressurization trace for a South American crude at corresponding reservoir temperature. HPM photomicrographs taken simultaneously during the isothermal pressure depletion experiment are superimposed on the same figure for ease of comparison. As can be seen, the HPM photomicrographs are consistent with the SDS trace; they help explain the observed trend and provide visual evidence (at the microscopic level) of the nucleation and agglomeration of asphaltenes during the isothermal depressurization process. APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A9 :1:10 250 ~ Æ!: - "5. 200 . :::¡ " . - - E 150 . C f ~ 'õ 100 ' '- . !: 0 a.. 50 - rnN'''"'''''-~"'--"-'''._'-''W~'~'.,"-''''-~---,--". ,. .--. -"""~'-'.'-"~^--"'''''-"''-'''''---'''-+-~-- "-- . -- -'-""""-'''---",-,,"'~''''''~' ""!:I~ i'ì ~ -'-:'-->"----"-~'--f-""---"-'-'-""'-"'-----'-" - Jr""""'''''''''''.'''''''''''''''''---i ,\ ~ ~ ~ .__..~ 0, 1500 3500 5500 1500 Pressure (psi a) 9500 11500 13500 (' Figure A. 7 - SDS Depressurization Trace of South American Live Oil & Corresponding HPM Photomicrographs at Tres ~!~t;t..jJ~f;~jl':JŠ9~tm.'\~-~Îg The SDS can be used to identify the onset of solids formation from a given crude oil due to isobaric and/or isothermal solvent/gas injection. The procedure involves charging a known amount of oil sample to the pre-cleaned and evacuated PVT cell. Thereafter, the PTL is measured and recorded continuously (in real time) while the solvent/titrant is being injected at the desired rate (continuous or discrete) and the resulting cell content is mixed vigorously. The experiment is stopped when a dramatic drop in PTL is observed as illustrated in example A.B. Qualitative description and/or interpretation of such a trace is provided below. The PTL increases more or less linearly as the concentration of solvent/titrant is increased isothermally and isobarically from zero 0N 0) to an intermediate level 0N*). This increase in PTL is likely caused by the decrease of fluid density with increasing concentration of the lighter n-alkane (making it easier for the laser light to pass through). Above W*, the PTL signal starts to decrease gently and progressively to noise level with further increase of n-alkane concentration. The drop of the PTL curve starting at W* is believed to correspond to the onset of asphaltene precipitation from the liquid. Hence, the onset point is defined to be the maximum concentration of solvent prior to the observed drop in PTL. APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A10 --'~""~""""-';""""""'~-~-"-'''''''''-''-''''''''.".''-'"'''''~''~'' :::r. t- ' a.. ' - . .... .c . 0)' :::J : 'tJ . ~: E : ! . I! : t- . ~. i : 0 . a.. . Wo -"-'-""'''''''''''-''-''->''-. W* en..t of A sp"''' n. Preclpl..tbn . ...,. ..... .................. .... Wei g.t Percent of Solvent Figure A.S - Typical SDS Titration Trace Depicting Onset of Asphaltene Precipitation Typical HPM Photomicrographs taken during titration of an asphaltenic crude oil with n-alkane are superimposed on the simultaneously measured SOS titration trace for the same oil as illustrated in Figure A.9. It is evident from this graphical comparison that the HPM is noticeably more sensitive than the laser-based SOS technique. This is plausible because the registered light transmittance represents the net effect of oil dilution with lighter n-alkane (resulting in decreased mixture density; hence, L T tends to increase) and formation of a dark solid "asphaltene" phase (L T tends to decrease). The maximum in the SOS titration curve occurs when the latter effect (solids formation) surpasses that of the dilution. This usually occurs when the asphaltene particles grow to a critical size and/or increase in concentration at a critical n-alkane concentration. i' .2 ::J ~ ~ :ö ... .!. .... .r:. C) :::; "0 S .... .e en c e .... - 0 ... CD ;c 0 a. I Asphaltene Onset l determined by HPM ~ ~ ~ Volume % n-C5 in n-C5-0il Mixture (arbitrary units) Figure A. 9 - SDS Titration Trace and Corresponding HPM Photomicrographs of Fluid Mixtures Prone to Asphaltene Instability APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A11 ~;{~'i.Øfi1m;;ltimitìi~.:;t.IB4141t'- The SDS can be used to measure the cloud point temperature of the fluid (both live and dead) at constant pressure. The maximum cooling rate is - 1°C/min. procedure involves charging a known amount of oil sample to the pre-cleaned and evacuated PVT cell. Thereafter, the PTL is measured and recorded continuously (in real time) while the cell temperature is being lowered continuously at constant pressure (using the computerized ODSR pump). The experiment is stopped when a dramatic drop in PTL is observed (see example Figure A.10). The temperature at which the drop occurs is interpreted as being the cloud point temperature for the fluid at the test pressure. -250 ¡ ¡--- Coo /in g ( . . . . ~ . . . . . . . . . . . . . . . . . . . 200 -..,...... ...... ,."....;.."....",..".. ,;.... ..;.. ,.....",..... ,." '.. 'r'''''''''''''''' ,.".., ,~..,',..,' '- ~ : : ¡ . . . . . . . . " . ~ ; . . . . . . . . ¡ ! ! I 5: ~:<~'»D~DJ::~::::r'::r:~ I I I I I 80 100 120 140 160 Temperature (OF) r ( [ "0 '3 ü: ~ 150 ::J e .c I- "0 ~ "E en c: ~ I- ~ a. ( ( ( " r ( ( ( ( ( ( ( l ( ( ( ( Figure A.10 - Typical SDS Cooling Trace Depicting Onset of Wax Precipitation [Hammami and Raines~ SPE JoumaJ1 4 (1999) 1-10] Typical partially cross-polarized HPM Photomicrographs taken during isobaric (15,000 psi) cooling of waxy crude oil are illustrated in Figure A.11. Asphaltene particles are also evident in the HPM photomicrographs for this crude. The atmospheric wax appearance temperature for the same sample was measured to be 48°C/118°F. l ( t ( APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A12 Particle,>; Wax C ,.,~~tajs Temperature =: 75.5"Cl168"F Temperature"'" 66. ¡VCI/52" F Temperature = 66.5"C/151, ¡OF Figure A. 11 - Cross Polarized HPM Photomicrographs of Waxy Crude Oil Taken During Cooling @ 15000 psi (1034 bar) [KamÐ et al., SPE Paper 62945, 2000J For filtration of live oil, ODBR retains a bulk precipitation/deposition apparatus, which may be used simply for removal of suspended solids in live oil or for quantification of solids precipitated at high pressures. Briefly, the apparatus consists of two stainless steel ODBR high-pressure cylinders (1 litre capacity) equipped with floating pistons. The cylinders are suitably connected to each other and a high- pressure 0.2 Jim Silver Millipore filter is placed in-line such that the contents of both cylinders can be displaced through it. A mineral oil hydraulic fluid and a motorised ODBR high-pressure displacement pump are used to displace the cylinder contents from one cylinder to the other through the filter for separation and analysis. The entire apparatus (excluding the displacement pump) is enclosed in a constant temperature controlled air-bath. The filtration can also be performed directly from the PVT cell by displacing the test fluid through a high-pressure 0.2 Jim Silver filter. This alternative is significantly cheaper than the bulk deposition apparatus described above, but the sample volume involved is barely sufficient to yield reproducible results. Ä.5 Dead Oil Pour Point In the modified ASTM D97 method, the oil is initially heated to a temperature 10°C above the wax disappearance temperature (determined by CPM) as opposed to heating the oil to a temperature 9 °C (for oils with pour point> 33°C) above the expected pour point required by ASTM D97. Briefly, this test involves the visual examination of the sample during cooling. At each temperature step (3°C/5.4°F decrement) the ASTM sample vial is poured or tipped to determine if the oil has any mobility, APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A13 Ä.6 Live Oil Pour Point A new experimental apparatus has been developed to measure Live Oil Pour Point (Karan et aI., SPE Paper 62945, 2000). The live oil pour point will be measured by a method similar to that described in section A.5 above. The live oil will be introduced in a sapphire cell (approximately 35 mm diameter and 150 mm high) initially filled with synthetic gas mixture at test pressure. Sample oil will be transferred to fill in up to a height of 50 mm. The oil is allowed to be cooled according to the ASTM D-97 method. The fluidity of the oil is checked every 2-3 °C by tilting the cell slightly and observing the movement of the interface. The temperature at which the interface ceases to move is deemed as the live oil Pour Point. I I Back Pressure Y Regulator ~ II Pressure Gauge Rotatabole . I , Shaft II I I I Temperature Indicator J f.....___l~< -)--------1 , , , , , , , , : 1'"11:1 ~ : : I .1 : : ¡ l~ 1 : : . :1!fi.1 Gas : : r: :..1)~,::¡ : . I I :1;>:1. J : : I ill. :11 . : r !I :1 j.. Oil! . 'ì:1 : , ! tll ¡ì :'1 ¡ :. : : : : : : : : ; : : ~._----_..._-------------_._---, Temperature Controlled Air Bath n ~ Gas Cylinder L ~~ 8= i - Positive Displacement Pump I I I ~ ~ Oil Cylinder I ¡ ~ Figure A.12 depicts the live-oil pour point apparatus schematically. ~lm1 ~= I . Positive Displacement Pump Figure A.12 - Schematic Diagram of the Live Oil Pour Point Apparatus The gel strength or yield strength of waxy crude oils have been successfully determined using the model pipeline test (MPT) apparatus. A high pressure MPT apparatus was recently developed and tested (Karan et aI., SPE Paper 62945, 2000). A schematic diagram of the model pipeline test apparatus is shown in Figure A.13 below. APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Page A14 Oilphase-DBR High Pressure Heated Lines Circulation Pump r-=:~::~~.._-'-----'_._.'-'--_.._.':,~,~:::~.-._-'--'.'"-=l-;==-~~=--- . r---L--____¡ ! ~ I I I :: I Back-Pressure I: , Regulator I I 1 I I I I I I I I 1 1 1 I I I 1 I 1 I I 1 I I I 1 I I I I 1 I 1 1___________1 þ & / -1 r--- JEFRI Pu~ ~....---- Test Coil , . Figure A.13 - Schematic Diagram of the Model Pipeline Test Apparatus The apparatus consists of two stainless steel coils - each 7.04 mm I.D. x 6.10 m long - that are placed in a temperature-controlled bath. The total volume of each coil is -240 cm3. However, for each experiment approximately 350 and 700 cm3 of oil sample are required depending on the whether one or both coils are used. The thermal pretreatment of the oil is an important part of the experiment. The oil sample is maintained at a temperature higher than the Wax Dissolution Temperature (WDT) in an oven for at least 12 hours to erase the thermal history. Dead Oil Charging: For dead oil testing, the experiment was initiated with the evacuation of the cleaned coils and the heating of the water-bath to the "Starting Temperature" (generally 10°C above WDT). After the bath temperature attained the starting temperature, the oil is charged in the coils and the connecting lines. The oil is then circulated through the coils for at least 30 minutes. This method helps to remove any trapped air bubbles from the coils, which could drastically affect the gel strength value. Upon completing the circulation, the pump is isolated from the coils whereas the flow line connecting the oil container/reservoir (containing oil at starting temperature) to the coil inlet is left open. Live Oil Charging: For live oil testing, the experiment is initiated with the evacuation of the cleaned coils and heating the water bath to the starting temperature. This is followed by charging the saturation gas (separator gas) to the coils and to the connecting lines. Next, the gas is pressurized to the test pressure, which is controlled by the back-pressure regulator. After the water bath attained the starting temperature, the live oil is filled in the coils and the connecting lines in a pre-determined sequence. The gas in the transfer/connecting lines and the coils is displaced through the back-pressure regulator. Cooling and Aging: The oil cooling under static condition is done under specified cooling rate. An example of the cooling rate profile to simulate the pipeline situation is demonstrated in Figure A.14. After the target test temperature or aging temperature is reached, the oil in the coils is allowed to age for at least 6 hours (or any specified period of time) to let the oil develop its gel strength. APPENDIX A SUMMARY OF OOBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A15 Ungelling: After the aging, the ungelling of oil is started by pressurizing the coils with nitrogen gas. For this purpose, the pump and the reservoir is isolated from the coils by closing the relevant valves. Nitrogen pressure is increased in steps of 1 psi over 0-10 psi range, 2 psi over 10-30 psi range and 5 psi thereafter. Exactly 5 minutes are allowed between each pressure increase for oil to ungel. The pressure at which the oil is observed to have started to move is deemed as the Yield Pressure. Gel Strength Calculation: The yield strength ('t) can be calculated from the measured Yield Pressure using a force balance equation and is reported below. 't = PD/4L P = ungelling pressure D = tube inside diameter L = coil length Note: The procedure (stress loading rate, aging time etc.) may be modified according to the requirements for a specific project. 60 Estimated pipeline cooling profile Simulated cooling profile u 45 ~ 30 ~ ~ 0.6 C/hr Aging ~ 15 ~ ~ ~ ~ 0 TIME, hr Figure A.14 - Experimental Simulation of Pipeline Cooling Profile ~~'.I*I~nll{. . .. ~. . The use of CPM for the study of wax crystallization is based on the fact that all crystalline materials rotate the plane of polarization of transmitted polarized light. Hence, by crossing two prisms on opposite sides of the oil sample, all light is initially blocked and the entire field of view appears black. On cooling, the crystallizing material appears as bright spots against this black background. This technique usually provides the most conservative (or highest) value of the crude oil cloud point temperature due the CPM's abaility to detect small crystals, Le. during early stages of wax crystallization. The experimental procedure involves preheating the dead oil sample in a water bath to 65°C for 30 minutes to melt the waxes and homogenize the sample. Next, the corresponding sample container is hand-rocked prior to transferring one drop of the oil to a special glass slide, which is then covered with a cover slip. The glass slide containing the oil sample is inserted in the CPM hot stage and the field of APPENDIX A Oilphase-DBR SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Page A16 view was brought into focus. The temperature of the programmable hot stage was then increased at a constant rate of 10 °C/min from ambient temperature to 10°C above the wax disappearance temperature (WOT). The WOT is defined as the temperature at which the last trace of wax disappears from the field of view upon heating. Next, the sample is allowed to equilibrate at the maximum temperature for 1 minute. Finally, the sample was cooled at 2°C/min from the equilibration temperature to O°C. The corresponding wax appearance temperature (WAT) is identified (off-line) as the temperature at which the first detectable bright spots (Le., wax crystal size in the order of 1 lm) emerged in the black field of view. An example of the W ATtesting using CPM is shown below in Figure A.15. T&8tJ8råtle = EIre \/VAT = 24°e T&lperctlre = ooe OIL A CD .... ::s .. ca .... CD D- E CD I- Ta.~c4ue=æ'e V\AT=41°e - - . .. ., . -.. - 8.... #111' - .... .-.. . .... '" ... --. ... -. ..'. J, " '.. . '.... .ø., "'- ". .'........... .,... -... ""... -- '.. .. ~ T& l¡)E:Icåre = ooe OILB Figure A 15 - Example photomicrographs of crude oil depicting wax crystals (bright spots) under polarized light. OOBR retains three (3) OOBR Core Flooding Apparatus rated to 10000 psi and 390°F. Each apparatus is divided into four subsystems: Injection System, Core Holder System, Production System, and Instrumentation. One of the Core Holder Systems consists of a stainless steel 316 cylinder 54.9 inches long with an internal diameter of 7 inches. The other two Core Holder Systems consist of a stainless steel 316 cylinder, 8 inches long with an internal diameter of 3 inches. The fluid pressure inside the core is controlled by movement of the displacement fluid to and from the apparatus using a ODBR positive displacement pump. Confining pressure is applied using water in the annular space between the sleeve and the stainless steel cylinder. Each Core Flooding apparatus is housed inside a steel shell equipped with a temperature controlled water bath. A re-circulation system insured constant temperature along the entire length of the system. APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Page A17 Oilphase-DBR The temperature is measured with a thermocouple and displayed on a digital temperature indicator, which is accurate within 0.1 °C. Each Core Flooding system is mounted on a support system, which allows for variability in the angle of dip, and is also mounted on an axially rotating mechanism that eliminated fluid segregation effects caused by gravity. Briefly, the procedure involves dissolving 2.5 g of dead oil/residue sample in an equal amount of toluene in a 300-cm3 flask. When the oil is fully dissolved, 40 cm3 of n-C7 is slowly introduced for each cm3 of toluene previously added. The flask is then capped and shaken thoroughly for 5 minutes and the precipitate is allowed to settle in subdued light for 2 hours with occasional shaking. Next, the contents of the flask are filtered through a filtering funnel (using a 0.22 flm filter) into a filtering flask under slight vacuum. The flask is then rinsed with n-C7 and the washings were transferred to the filtering funnel. The precipitate is then washed until the effluent is colorless. The filtering funnel and the original flask are then dried at 105°C. Finally, the filtering funnel and the flask are re-weighed to quantify the asphaltenes (n-C7 insolubles). - Figure A.16 depicts saturates-aromatics-resins-asphaltene (SARA) fractionation protocol. Briefly, the procedure involves fractionation of a dead oil into two cuts by distillation at 270°C (Le., the boiling point of C1S). The C15- fraction «270°C) is then subjected to supercritical fluid chromatography (SCF) to determine the aromatics-to-saturates ratio. The C1s+ residue (> 270°C) fraction, on the other hand, is dissolved in n-heptane solvent at 50°C; the mixture is filtered hot (i.e., at 50°C) to remove undissolved asphaltenes (defined as hot n-heptane insolubles). Following this, the filtrate is cooled and filtered at - 10°C. The resulting precipitate (essentially wax insoluble at -10°C) is then weighed and denoted as the wax content. The wax fraction may be dissolved in CS2 and analyzed by high temperature gas chromatography (HTGC) to C100+. The assignment of the weight percent data to the appropriate n- paraffin and iso-paraffins will be based on the measured retention times of the calibration standard n- alkanes. The weight percent of iso-paraffins for a given carbon number will correspond to the sum of the area percent values of the peaks in between two consecutive (neighboring) n-alkanes. Subsequently, the solvent is evaporated from the de-waxed and de-asphalted filtrate. The remaining maltenes are dissolved in n-Cs (Le., carrier solvent) and injected into a packed column filled with silica and alumina. The silica section of the column strips out the polars (Le., resins), the alumina section removes the aromatics and, hence, only the saturates initially elute through along with the carrier solvent (Le., Cs). The column is then washed with a medium strength polar solvent to remove the trapped aromatics. Finally, the column is washed one last time with a fairly strong polar solvent to recover the remaining polars/resins. Typically, the saturate fraction recovered is observed to be white and opaque, like candle wax, whereas the aromatic fraction appears to be brownish and the resins have a very dark color. APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A18 ~ < 270°C «518°F) . SFC ¿{;:turates~ CAromatics~ ¡ WAX (SATURATE$) G~v DISTILLATION I ~ HOT N_HEPTANE SOLUBLES I COOL TO -100C/14Of & FILTER I ~ > 270°C (> 518°F) I ADD N_HEPT ANE HEAT TO 50oC/1220F & FILTER I ~ dOT N_HEPTAþE INSOLUBLES IIAsphaltenes" ¡ De-Waxed + De-apshalted Oil (Maltene) COLUMN CHROMATOGRAPHY .. + C RESINS =:> ~ROMA TIC§) Figure A. 16 - SARA Fractionation Protocol APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Page A19 Oilphase-DBR APPENDIX B DETERMINATION OF OIUBRINE INTERFACIAL TENSION APPENDIX B Determination of Oil/Brine Interfacial Tension Oilphase-DBR Page BO 07/10/2002 WED 15:52 FAX 7804501668 OILPHASE - DBR ~ 0011009 Ræãl~~f DETERMINATION OF OIUBRINE INTERFACIAL TENSION Prepared by PRI business unit of Alberta Resc:arch Council June 2002 Confidential APPENDIX B Determination of Oil/Brine Interfacial Tension Oilphase-DBR Page B 1 07/10/2002 WED 15:52 FAX 7804501668 OILPBASE - DBR APPEND Determination of Oil/Brine Interfacial Tension DBR groups 1FT Project No. 3700016 June 2002 TABLE OF CONTENT 1.0 EXECUTIVE StJl\fMARY ""'''''''''''''''''"111'1'''''' '''''''''''''".''''I'''''''M'''''' UH" 1.............11. It 1"111.........1 2.0 EXP.ERIM:ENTAL PROCEDURES ...............-.........'.-. -'k .... ",.""'..""',,,,"',101.",' . u. --~.._.-- 1 2.1 OIL AND BRINE SAMPLES ..'.__...1___- --, .---- . .- . ..--_.3 3.0 --...-_...3 RESULTS ----- ----------.------- - - 3.1 IFf OF DEAJ)..Q~ SYSTEM-- ,--.' uun'nn--numm'.--.mmmm.m--m...._''''''.....3 3.2 IFI' OF LIVE OILIBRINE SYSTEM -' - ----_.....3 4.0 REFERENCE -- -- -,' . ,-...,,,- ...... . . ----- --5 LIST OF TABLES TABLE b FLUID DENSITIES ----- . '. ~..- - ------ .,....- -- .. ....- ---.- ..-.---.- -.. --4 TABLE 21 DEAD OßJBRINE 1NTERF ACIAL TENSION AT 121 <T AND 100 PSIG .......................4 TABLE 3: LIVE OILlBRINE lNTERFAClAL nNSlON AT 254:; ANn S17S }>SJA--...-....A LIST OF FIGURES FIGURE 1: DROP SHAPE OF DEAD OIL IN BRINE AT 100 PSI AND 121 of .....-..-....--6 FIGURE 1: DROP SHAPE OF LIVE OIL IN BRINE AT 5175 PSIA AND 154.5 <T .............._.......7 PRIlARC Page B2 IaJ 002/009 -DBR 07/10/2002 WED 15:53 FAX 7804501668 OILPHASE - DBR DBR ¡!J'OUpS IFf Project No. 3700016 June 2002 1.0 executive Summary Interfàcial tension (1FT) between a crude oj) sample and produced brine had been determined using Axisymmetric Drop Shape Analysis (ADSA) ~hnique. The IFf between stock tank oil and produced brine at 122 OP and 200 psig was determined to be 16 mN/m. The 1FT between the saturated oil and produced brine at 5175 psia and 254.5 "F was determined to be 25.9 mNlm 2.0 Experimental procedures The experimental system consists of a high pressure high temperature cen, made up of Titanium and Hastenoy parts with glass windows on opposite sides. The cell is capable of opendmg at pressures up to 70. MPag and temperatures up to 200 .,c. The glass windows allow the capture of dropIbubble profile images by using a light source on one side and a camera system on the opposite side. Elevated pressures are aclùeved through the use of fluids handling system consisting of pistoned pressur<>-vessels, high pressure pumps and a back-pressure regulator. Elevated temperatures are achieved by the use of a Blue M oven as a source of heat. The camera system. is connected to an NTSC monitor and a personal computer equipped with an image capture board and the image analysis software including the Axisymmetric Drop Shape Analysis (ADSA) program to iteratively calculate the interfacial tension. The optical cell details are quite similar to the contact angle cell descn"bed elsewhere!. The pendant drop technique was used in this study which consists of oil drops hanging from a capillary tube within the surrounding brine solution. The bottom part of the optical table supporting the test cell and the camera system is loaded with sandbags to minimize vibrations and enhance clæity of the profiles of the: drops and bubbles captured on the computer hard-drive. The cell housing also contains a live oil reservoir equipped with a piston driven by high pressure water to enable the maintenance of the fluids at reservoir temperatures and pressures at all times during the course of the experiments as well as to flow the oil in the fonn of droplets within the field of view of the camera which sends the drop profile images to be captured by the computer. PRIlARC APPENDIX B Determination of Oil/Brine Interfacial Tension Page B3 I4J 003/009 Oilphase-DBR 07/10/2002 WED 15:53 FAX 7804501668 OILPBASE - DBR DBR gf01JP8 1FT PIOjectNo.3700016 June 2002 Interfacial tension, being very sensitive to fluids contamination. imposes cleanJiness as a basic requirement during experimentation. The titaniUIt1 and Hastelloy lines and valves were flushed with 1arge amounts of water to remove any excess brine or salt which may have accumulated within the system. A dilute solution of nitric acid and hydtochloric acid can be used when required. The lines were then flushed with acetone to remove residual water. The lines were then flushed with methylene chloride (to remove trace hydrocarbons), and with acelone to remove any temaining methylene chloride. A final flushed wi1h high purity HPLC grade isopropyl alcohol was used to remove any remaining contaminants. The lines were then dried by purging with high grade nitrogen. The titanium parts of the cell and injection needles were cleaned using the same sequence of solvents. The quartz windows, the ruby calibration sphere was cleaned in a heated bath of sulphuric acid and ammoniwn persulfatc for two hours. These components were subsequently rinsed with deionized water. ( ( r ( ( Images are acquired using the digitization apparatus in the following manner. Drop images are displayed and centered on the NTSC monitor. The video camera, optical cell, and light soun;c are arranged in a collinear fashion, When the light intensity is at the appropriate level, so that it is within the dynamic range of the video camera, the drop profile can be brou¡ht into focus. The image of the drop p¡ofile is then captured in a fi:ame buffer and its digital representation is then saved on the computer bard-drive. After a set of images have been saved on the computer hard-drive, each image is individually recalled and analyzed. This is done by reading the desired image back into the video board's ftame buffer. First a low pass digital filter is used to smooth out the jagged interface. Then a Laplacian low dimensional second derivative is applied to the filtered image to identify the drop edge. The image is now seanned along the drop edge. This supplies the x-y co-ordinate data for a representation of the drop interface. The c0- ordinate data are converted into polar co-ordinates and then fitted using the method of cubic splines. Once the data has been appropriately fitted, the fitted function is then converted back into Cartesian co-ordinates. It is this fitted function that is used to obtain ( ( ( up to 50 or 60 points on the inteñace as input to the ADSA program for calculating the ( PRIlARC (, t ( ( APPENDIX B Determination of Oil/Brine Interfacial Tension Page B4 ~ 004/009 2 Oilphase-DBR 07/10/2002 WED 15:54 FAX 7804501668 OILPHASE - DBR DBR groups 1FT Project No. 3700016 Juno 2002 interfacial tension using equation 1. DQtails of tho ADSA program and its use in 1FT measurement can be obWned £rom the reference of Cheng et al2 . ðP = Y (l/Rl + 1/R2) (1) where Y is the interfaciaI tension, RI and R2 a.:rc the principal radii of curvature of the oil drop AP is the pressure difference across the interface 2.1 Oil and Brine Samples The stock tank crude oil, saturated live oil and produced brine samples were supplied to us by D.B. Robinson Research Ltd. The density of the stock tank: crude oil and produced brine were detennined with an Anton Paar densitometer. Density of the live oil was provided to us by DBR Research Limited. 3.0 Results 3.1 1FT of Dead~lllbrIne system The values of the interfacial tension between the produced brine solution and the stock tank crnde oil are presented in Table 2. The average value of the measurements is 16 mNIm. This value is significantly smaller than the nonnal 1FT value of of between 30-40 mNlm for crnde oil and water. An image of the oil drop captured during the test is presented in Figure 1. 3.2 1FT of Uve Oillbrine system The interfacial tension between the produced brine solution and the live oil at 5175 psi and 254 F are presented in Table 3. The average value of the measurements is 25.9 mNlm. An image of the oil drop captured during the measurement of the liveoillbrine system is presented in Figure 2. PRI!ARC APPEND.. . - Determination of Oil/Brine Interfacial Tension Page B5 I f 005/009 - ..,... .___-DBR 07/10/2002 WED 15:54 FAX 7804501668 OILPBASE - DBR r ( ( ( ( ( (, ( r ( [ ( t l ( APPEND Determin Interfacial Tension t ( ( ( DBR groups 1FT Table 1: Ftuid Densities s~ tank oil density at 200 psi and 122 ~ (gm/m1) Produced brine density at 200 psi and 122°F (gm/ml) live oil density at 5115 psi and 254 OP (gm/ml) - ,ProdÜced ~ density ~t 5175 psi and ~S4OP (gm/ml) 0.814 1.009 0.52 0!)7 Project No. 3700016 June 2002 Drop # 1 2 3 4 ,~-, 6 7 8 Average IFf Table 2: Dead OillBrlne IDterfacial Tension at 122 IIJ' and 200 psig Calculated 1FT mN/m 16.3 16.2 16.) 15.8 15.8 15.7 15.7 15.8 16.0 Table 3: Live OßIBrine ~D~rfacialTeDsion at 254 o¡. and 5175 psia DRQP# 1 2 3.. 4 S 6 7 8 ~verage 1FT - .- . -. PR1IARC 26.7 26.2 25.7 25.6 25.6 25.8 25.8 26.0 25.9 Page B6 141 006/009 4 -DBR 07/10/2002 WED 15:54 FAX 7804501668 OILPHASE - DBR APPEND Oetermin Interfacial Tension DBR groups IFf Project No. 3700016 June 2002 4.0 REFERENCE 1. A new technique for reservoir wettability characterization, D.N. Rao M.G. Girard, Canadian Jouma! ofPettoleum Technology. Jan. 1996 Vol. 35. NO.1 2. Chen& P., Li D., Bom~ L., Rotenberg, Y.. and Neumæm. A.W.. ffAutomation of Axisymmetric Drop Shape Analysis for Measurement of Interfàcial Tensions and Contact Angles", Colloids and Surfaces, 43, pp. 151-167, 1990. PRIlARC Page B7 III 007/009 5 -OBR 07/10/2002 WED 15:54 FAX 7804501668 OILPBASE - DBR \ g 008/009 DBR group5 1FT Project No. 3700016 J\lDI: 2002 ~r," " . .,- ....... '" "...,.... .... '"'',i.''' ..": ...... .,.... .. ... "" '\ . . :' ,'\ ( [ ( [ ( ( ( t ( t ( ( C ( ( ( ( ( ( ( l ( L ( , ' . ~ to" ". ,.' "... " I i .' ; , . to. . ; " ., I ~.. : . . ' . . '..'t' j , . , " ; I ":.. . " . . 0' . ,'" ~) ~. ". '.. Figure 1 : Drop shape of dead 011 in brine at 200 psi and 122 of PRIlARC 6 APPEf\ Determination of Oil/Brine Interfacial Tension , ;e-DBR Page B8 07/10/2002 WED 15:55 FAX 7804501668 OILPBASE - DBR ~ 009/009 DBR groups IFf Project No. 3700016 June 2002 Figure 2: Drop Shape of Live Oil in brine at 5175 psia and 254.5 of PRIlARC 7 APPENDIX B Determination of Oil/Brine Interfacial Tension Oilphase-DBR Page B9
