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Home My WebLink About200-073Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~_ -4~_'7~ Well File Identifier History RESCAN DIGITAL DATA OVERSIZED (Scannable) GralOr items: yscale items: [] Poor Quality Originals: Other: [] Diskettes, No. Other, No/Type TOTAL PAGES: ¢¢ NOTES: ORGANIZED BY: BEVERLY BREN ~ SHERYL MARIA LOWELL [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [3 Other ISl~ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN~ SHERYL MARIA LOWELL SCANNED BY: BEVERLY ~N VINCENT SHERYL MARIA LOWELL DATE:/~--/ Isl RESCANNEDBY~ BEVERLY/~ VINCENT SHERYL MARIA LOWELL DATE; General Notes or Comments about this file: Quality Checked (done} RevlNOTScanned.wpd • • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, June 06, 2013 2:10 PM To: 'Stan Porhola' Cc: Donna Ambruz; Chad Helgeson; Wade Hudgens - (C); Luke Keller, 'Davies, Stephen F (DOA) (steve.davies @alaska.gov)' Subject: RE: Change to Sundry 313 -236 (Move Bridge Plug Set Depth) Stan, You have verbal approval to modify sundry 313 -236 and set CIBP at 9820' md. (650 ft deeper). As you mention below the PTD will need a revised plan to be submitted to the Commission before drilling starts. Send a new 401 form, cover page with a new directional and any other changes to the well plan.... the PTD will be a revision. The same PTD number will be used 213 -062. prD Z oo — D73 Guy Schwartz Senior Petroleum Engineer JUN �� AOGCC SCANNED 907 - 444 -3433 cell 907 -793 -1226 office From: Stan Porhola r,t.arltc.sporho( _:a.;;ii`oF ?.corn Sent: Thursday, June 06, 2013 12:24 PM To: Schwartz, Guy L (DOA) Cc: Donna Ambruz; Chad Helgeson; Wade Hudgens - (C); Luke Keller Subject: Change to Sundry 313 -236 (Move Bridge Plug Set Depth) Guy, Per our conversation, Hilcorp is requesting to change the set depth of the Bridge Plug (Sundry 313 -236) in well SCU 23A- 09 (PTD 200 -073). The change will move the bridge plug from +/- 9,170' to +/- 9,820' (650' deeper). This change is being requested in order to avoid sidetracking through potential high - pressure water zones in the Tyonek. Additionally, we will be running the gamma ray log from 10,000' to surface (originally 9,500' to surface). Attached is an updated proposed schematic for SCU 23A -09. An update to the Permit to Drill for well SCU 12B -09 (PTD 213 -062) for the change in the window depth and directional plan will be submitted separately. Regards, Stan Porhola :_; ,c rtr ir;>>s r ngineci Nor th Kenai Asset Team Hilcorp Alaska, LLC 1.., {ftio. -. i, '. # }. j 1 7 7743-1 , 1') NOT -8228 1 Soldotna Creek Unit • • Well SCU 23A -09 PROPOSED SCHEMATIC Proposed: 06/06/13 ' PTD: 200 -073 Ilse „r„ ;1641.. LIR API: 50- 133 - 10126 -01 CASING DETAIL RKB= 18.85' Size Wt Grade Conn ID Top Btm 20” - - - 32' 1 11 -3/4" 47 J -5-5 8rd 11.000" Surface 2,009' 7" 29 N -80 Buttress 6.184" Surface 288' 20 7" 26 N -80 Buttress 6.276" 288' 1,048' 7" 23 N -80 Buttress 6.366" 1,048' 4,715' 7" 26 N -80 Buttress 6.276" 4,705' 6,543' 7" 29 N- 80/P110 Buttress &8rd 6.184" 6,543' 10,192' Window 11 -3/4" 3 -1/2" liner 9.3 1 -55 Hydril 511 2.992" 10,095' 10,935' slotted 24 slots /ft 1/8" wide 2.5" long 12 slots /row JEWELRY DETAIL No. Depth ID OD Item El DV Collar @ 1 18.85' - - Tubing Hanger, 7- 1/16" x 3 -1/2" Butt., Type" H" BPV 6,796' profile. CL prep. W/ 3 -1/2" SC buttress space out pups 44' Xover, 3 -1/2" buttressx 8rd 2 +/_ 4.220 - s.i P 3 10,095' 5.25" 5.75" ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve 2 10,110' 4.438" 5.875" Baker HMC liner hanger 1 bbl of cement _- .____�_.. —__ .., 4 10,130' 2.813" 4.000" Baker X nipple, 2.813" ID, PX Plug proposed topes W 5 10,195' Baker Bottom Trip Whipstock 10,062" 3 • � , ,,, 6 10,216' 7" retainer • " • • . 7 10,935' 2.992" 3.5" 3 -1/2" liner shoe i PX Plug Set in X- Nipple 4 --->< : ___ _ I G1 _10,150'- 10,168' \\ \\ Top of \ l \ \ \ ` . window . @10,192' s s G2 H1 �, H2 6 - -; H3 = I. H5 6 TD = 10,960' MD / 10,383' ND MAX HOLE ANGLE = 95 deg Updated by STP 06 -06 -13 • oF' 7•1 • 0) \ \I' / %is THE STATE Alaska Oil and s ,,, GOVERNOR SEAN PARNELL 333 West Seventh Avenue *g' Anchorage, Alaska 99501 -3572 Op, ALAS �� 9 e, Main: 907.279.1433 Fax: 907.276.7542 SCANNED MAY 2 0 2 013 Chad Helgeson 3 Operations Manager a 0 0 `" 7 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit (SCU) 23A -09 Sundry Number: 313 -236 Mr. Helgeson: Dear M . eson: g 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 P1Foerster Chair DATED this ! 7da of May, 2013. Encl. # 0 1 STATE OF ALASKA h Y ,, ., ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS r ' CC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redril El. Perforate New Pod ❑ Repair WerJ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing Time Extension ❑ Operations Shutdowl ❑ Re -enter Susp. Wel ❑ Stimulate ❑ Alter Casini Other. ❑ 2. Operator Name: N Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to Drill Number. mbe Exploratory ❑ Development el • 200 -073 • 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ S ervice ❑ 6. API Number Anchorage, Alaska 99503 60-133-10126-01 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123A ' Soldotna Creek Unit (SCU) 23A -09 . Will planned perforations require a spacing exception? Yes ❑ No El ' 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA028997 ' Swanson River / Hemlock 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): 10,960 • 10,383 • 10,936 10,382 WA N/A Casing Length Size MD ND Burst Collapse Structural Conductor 32' 20" 32' 32' Surface 2,009' 11 -3/4" 2,009' 2,009' 3,070 psi 1,510 psi Intermediate Production 10,192' 7" 10,192' 10,191' 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3 -1/2" 9.3# / L-80; 9.3# / J-55 10,130'; 10,935' Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): ZXP Liner Top Packer; N/A 10,095' MD, 10,094' TVD; N/A 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: • Detailed Operations Program n BOP Sketch fl Exploratory n Stratigraphicn Development n Service n 14. Estimated Date for 15. Well Status after proposed work: , i> Commencing Operations: 05/20/13 Oil ? r ; Gas ❑ WDSPL El Suspended " 16. Verbal Approval: Date: WINJ ❑ S 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 Chad Helgeson Phone: 907- 777 -8405 Email chelgesont hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature .G7 j� Phone 907 - 777 -8405 Date $ / ?/I 3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3i J 2 -23(0 Plug Integrity [� BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: /- 4- 3 00 0 r ..,, - ... 6 O P (cS � / r i, Al lry n .._.1..e__ p/, ) P /4 c. e w�.e_..-c� -`p/�/b `-z `!� ,, e< 2 4.4 Cr Z. //Z G ) �" RBr MSC,. MAY 17 201. Spacing Exception Required? Yes ❑ No LJ Subsequent Form Required: / D -- L i 0 7 / 1) APPROVED BY Approved by: f COMMISSIONER THE COMMISSION Date: 3 j 7 . / . / �/� /3 Submit Form and p . Form 10-403 (Revised 10/2012) App v d I n id r 2 montlfg from the date of approval. /ogl A ts' uplicate t 7. • , Well Prognosis Well: SCU 23A -09 Hilcorp Alaska, LLC Date: 5/8/13 Well Name: SCU 23A -09 API Number: 50- 133 - 10126 -01 Current Status: Oil Producer Leg: N/A Estimated Start Date: May 16` 2013 Rig: Williams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 200 -073 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Jason Ewing (907) 777 -8444 (0) AFE Number: Current Bottom Hole Pressure: — 1,060 psi @ 10,220' TVD SI Pressure survey completed 3/22/12. Maximum Expected BHP: — 1,060 psi @ 10,220' TVD Max. Allowable Surface Pressure: —0 psi (Based on pressure gradient of 0.1 psi /ft of TVD) Brief Well Summary SCU 23A -09 has been identified as a candidate for re- drilling. The new wellbore will utilize the existing casing program down to 9600' MD/TVD. The well will be sidetracked at 9055', and target the Hemlock formation to the South. The new well will be called SCU 12B -09. The purpose of this work /sundry is to abandon the current productive interval and prepare the wellbore for • redrilling operations. A 10 -401 PTD application is also attached for the drilling & completion of SCU 12B -09. Notes Regarding Wellbore Condition 1 CeAcut. l G t w.c! • q poor prda,e'- 4 f sr a�•( ciw41 4 J iictn. • Current well status is a producing oil well on gas lift (121 bwpd, 5 bopd, 206 mcf gpd). • Brief Procedure: 1. RU slickline, RIH and pull orifice on bottom gas lift mandrel at 10,051'. 2. Set PX plug in X- nipple at 10,130'. 3. Bleed gas to production system. Vent gas after tubing pressure is below 150 psi, thought tank w/ gas buster. 4. RU pump and pump down production annulus with produced water, circulate through gas lift mandrel and up tubing to circulate out gas and oil from the system. 5. MIRU Williams Rig on SCU 23A -09. 6. Notify AOGCC 24hr in advance of BOP testing. 7. Install & test BPV. 8. N/D tree. 9. N/U and test BOP test same to 250psi low /3,000psi high, annular to 250psi low /1,500psi high. 10. Pull tubing hanger & seal assy (do not exceed 75% of the tubing string weight). L/D hanger, 3 -1/2" tubing, and 3 -1/2" seal assy. a. If tubing does not pull free, RU a -line, RIH and cut tubing at 10,075'. b. POH and LD tubing. 11. RU E -line 12. RIH with cement dump bailer and dump bail 1 bbl of cement, on plug @ 10,130' (58' of cement from 10,130' to 10,062'). (Waiver required from 20AAC25.112(c)(1) &(2)... for the distance from ' — sf , D H • • • Well Prognosis Well: SCU 23A -09 Hilcorp Alaska, LLC Date: 5/8/13 hydrocarbon bearing strata because of the 3 -1/2" slotted liner. There will be 62ft from the top of the slotted liner to the plug.) Wait on cement, RIH and tag top of cement in 7 ", should be at 10,080'. dl a f. j// 13. RU GR /CCL from 9,500ft to surface. C M IT 36/ch 14. Pressure test plug and casing to 2,500 psi or 30 min with 8.5 ppg PW. 15. RIH and set CIBP at "'9170' MD. (set 3 -5ft above casing coupling, not in a coal seam) 16. RD E -line. 17. ND BOP's 18. Change out tubing head. N/U dry hole tree. RDMO Williams rig. Zo M I�u 5A-X5• (4? Z(. �7: Bt r S s 2 2. pa, w h: p 3 C t Q 7/ S -� Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics • • Soldotna Creek Unit Well SCU 23A -09 SCHEMATIC As Completed: 07/11/00 PTD: 200 -073 Hilcora Alaska. LL(: c-4.4 API: 50- 133 - 10126 -01 CASING DETAIL RKB= 18.85' Size Wt Grade Conn ID Top Btm 20" - - - 32009' 1 11 -3/4" 47 J 55 8rd 11.000" Surface 2,' 7" 29 N -80 Buttress 6.184" Surface 288' 20" 2 7" 26 N -80 Buttress 6.276" 288' 1,048' 7" 23 N -80 Buttress 6.366" 1,048' 4,715' 7" 26 N -80 Buttress 6.276" 4,705' 6,543' 7" 29 N- 80/P110 Buttress &8rd 6.184" 6,543' 10,192' Window 11 -3/4" _ 3 -1/2" liner 9.3 J -55 Hydril 511 2.992" 10,095' 10,935' 3 slotted 24 slots /ft 1/8" wide 2.5" long 12 slots /row TUBING 3-1/2" 1 9.3 1 L -80 8rd 1 2.992" Surf 10,130' 4 IIII JEWELRY DETAIL IMI ❑ DV Collar @ No. Depth ID OD Item Eli 6,796' 1 18.85' - - Tubing Hanger, 7- 1/16" x 3 -1/2" Butt., Type" H" BPV profile. CL prep. W/ 3 -1/2" SC buttress space out pups 44' Xover, 3 -1/2" buttressx 8rd 2 2.992" 3.500" 3 -1/2" N -80 9.2 ft/lb 8rd. tubing 3 2,500' 2.867" 5.500" Methanol Injection Mandrel Macco SFO -1CI with 3/8" control line strapped w/168 x1 -1/4" SS bands I. 4 2.867" 5.313" Macco SFO -1 GLMs, BK -2 latches, R -1 valves r 2,604' GLM #1 5 11.M11 1...= Ip / o4S 4,599' GLM #2 6a 4a 6,388' GLM #3 7,809' GLM #4 8,642' GLM #5 6b 9,452' GLM #6 10,051' GLM #7 orifice 7 4a 10,130' 2.992" 4.000" Tubing Seals, 13' long x 4.000" OD w/4.125" locater G1 5 10,095' 5.25" 5.75" ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve , ' , _10,150'- 10,168' 10,110' 4.438" 5.875" Baker HMC liner hanger ', I , 6a 10,117' 4.000" 5.625" Seal Bore Extension �, �, 6b 10,133' 3.437" 5.500" KOIV flapper, 3.437" ID after flapper knocked out on , ‘.1---- Top of 7/18/00 with slickline weight bar. window 7 10,130' 2.813" 4.000" Baker X nipple, 2.813" ID 8 , ` @ 10,192' 8 10,195' Baker Bottom Trip Whipstock ` ` 9 10,216' 7" retainer ` G2 10 10,935' 2.992" 3.5" 3 -1/2" liner shoe H1 H2 9 H3 HS 10 TD = 10,960' MD / 10,383' TVD MAX HOLE ANGLE = 95 deg Updated by DMA 05 -08 -13 r • Soldotna Creek Unit Well SCU 23A -09 PROPOSED As Completed: 05/20/13 PTD: 200 -073 Hacora Alaska. u.c API: 50- 133 - 10126 -01 CASING DETAIL RKB= 18.85' Size Wt Grade Conn ID Top Btm 20" - - - 3 1 11 -3/4" 47 J -55 8rd 11.000" Surface 2,009' 4 7" 29 N -80 Buttress 6.184" Surface 288' 20"_, . 7" 26 N -80 Buttress 6.276" 288' 1,048' 7" 23 N -80 Buttress 6.366" 1,048' 4,715' 7" 26 N -80 Buttress 6.276" 4,705' 6,543' 7" 29 N- 80 /P110 Buttress &8rd 6.184" 6,543' 10,192' 11-3/4", — 3 -1/2" liner 9.3 J -55 Hydril 511 2.992" 10,095' 10,935' a% ' slotted 24 slots /ft 1/8" wide 2.5" long 12 slots /row .../ B- J EWELRY D ... ' ' No. Depth ID OD Item ' El DV Collar @ 1 18.85' - - Tu . g Hanger, 7- 1/16" x 3 -1/2" Butt., Type" H" BPV 6,796' " , rofile. CL prep. W/ 3 -1/2" SC buttress space out pups 44' Xover, 3-1/2" buttressx 8rd p _ 2 10,095' 5.25" 5..; ' ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve Cz6 J 11111i 10,110' 4.438" .875" Baker HMC liner hanger o 3 10,130' 2.813" 4.000" Baker X nipple, 2.813" ID, PX Plug 3 4 10,195' Baker Bottom Trip Whipstock /6,°.°41 5 10,216' 7" retainer e 4 ,. - 6 10,935' .•92" 3.5" 3 -1/2" liner shoe 2 . jp 1 - 3 ► G1 ' ' 10,150'- 10,168' t Top of ,.f `..f 1 .,, °""' "• �, t— window @ 10,192' 4 /G •73 G2 H1 ` H2 5 H3 • ■ 115 6 TD = 10,960' MD / 10,383' ND MAX HOLE ANGLE = 95 deg Updated by DMA 05 -08 -13 q fli 0 • Swanson River SCU 23A -09 05/08/2013 11&I.^..rp %Ida a. 1.1.1. Swanson River SCU 23A -09 Williams BOP 2013 • • 111 111 111 III 111 111 111 111 3.46' Shaffer 11 '5M 1111 111 111 111 111 _____-- Shaffer LWS _ 0 2.75' 11 "5M 1 2 1/16 10M Choke and Kill Valves ® . � 1 . 111 111 111 111 111 . ^ . ; , ■, H -� - - - • " 1 _ 2.00' I , ,: 111 111 111111 Ifl y 1 'I' E I e I. M IA 1 ∎,: it MI 1 t 'S !ii.i.. 4 1 , . i., : ,1 k r : i 6,_ Erigaral i ii ' Ili. - ■1 1 • /�' Itit . i., • • Soldotna Creek Unit 'r , H Well SCU 23A -09 PROPOSED As Completed: 05/20/13 PTD: 200 -073 Ililio i, AIa.l a. I.I,c API: 50- 133 - 10126 -01 CASING DETAIL RKB= 18.85' Size Wt Grade Conn ID Top Btm 20" - - - 32 ' 1 11 -3/4" 47 1 -55 8rd 11.000" Surface 2,009' 7" 29 N -80 Buttress 6.184" Surface 288' 20" 7" 26 N -80 Buttress 6.276" 288' 1,048' 7" 23 N -80 Buttress 6.366" 1,048' 4,715' 7" 26 N -80 Buttress 6.276" 4,705' 6,543' 7" 29 N- 80 /P110 Buttress &8rd 6.184" 6,543' 10,192' Window 11-3 . 3 -1/2" liner 9.3 1 -55 Hydril 511 2.992" 10,095' 10,935' slotted 24 slots /ft 1/8" wide 2.5" long 12 slots /row JEWELRY DETAIL No. Depth ID OD Item ❑ DV Collar @ 1 18.85' - - Tubing Hanger, 7 - 1/16" x 3 - 1/2" Butt., Type" H" BPV 6,796' profile. CL prep. W/ 3 - 1/2" SC buttress space out pups 44' Xover, 3 -1/2" buttressx 8rd 6.184" iB 3 10,095' 5.25" 5.75" ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve 2 10,110' 4.438" 5.875" Baker HMC liner hanger 1 bbl of cement _ __ 4 10,130' 2.813" 4.000" Baker X nipple, 2.813' ID, n K ? proposed top -- 5 10,195' Baker Bottom Trip Whipstock 10,062" 3 , . - " ' ` , 41 , ' 6 10,216' 7" retainer 7 10,935' 2.992" 3.5" 3 -1/2" liner shoe t • , ' * N. �... PXPIugSetinX- � Nipple - 4 L _ ' G1 _10,150'- 10,168' ■ , 5 J ' Top of %~"— window % @ 10,192' G2 H1 s H2 6 �� H3 H5 7 "4 - - 6 TD = 10,960' MD / 10,383' TVD MAX HOLE ANGLE = 95 deg Updated by CAH 05 -15 -13 • • Schwartz, Guy L (DOA) From: Luke Keller <Ikeller @hilcorp.com> Sent: Thursday, May 09, 2013 3:31 PM To: Schwartz, Guy L (DOA) Cc: Paul Mazzolini; Kate Kaufman; Kevin Eastham Subject: SCU 12B -09 10 -401 For Approval Attachments: SCU 12B -09 10 -401 Submitted 5- 9- 2013.pdf; Surface Use Plan - 12B- 09.pdf; SCU 23A -09 AOGCC 10-403 Submitted 05-08- 13.pdf; SCU12B -09 Version #2 Geographic Wellpath Report.xls .� z_zno - 0 73 Guy, Enclosed for review and approval is the application for the Permit to Drill the Soldotna Creek Unit 12B -09. SCU 12B -09 is a development oil well to be re- drilled in a NW direction from the existing well SCU 23A -09. The new well will utilize the existing sing program down to 9148' MD. Integrated subsurface and 3 -D geological interpretations, in conjunction with previous production data indicates that stranded oil reserves remain in the Hemlock 1 -10 benches south of the B fault. High on structure, the H7/8 & H10 are the primary targets. Reserves aren't recoverable in existing wellbores due to lack of take - points or mechanical condition of other existing wellbores in the fault block. The base plan is a slightly deviated wellbore reaching a maximum inclination of 44.7 deg and a 1551' vertical separation at TD. Total depth is planned at 11,350' MD / 10,814' TVD. Drilling operations are expected to commence approximately May 30th, 2013, immediately after wellwork is finished on the current sidetrack, SCU 41A -04. The Doyon Arctic Fox will be used to drill and partially complete the wellbore. The Williams rig or AWS #1 will be used to perforate the liner and run the 3 -1/2" production tubing. A separate sundry will be issued for these operations. Prior to the commencement of drilling operations, the Williams Pulling Unit will be mobilized and conduct wellbore preparation operations for the sidetrack operation. A 10 -403 is attached and covers these operations. An electronic copy of the directional plan is attached. (2) hard copies of attached documents will be couriered to your office today (5 -9- 2013). Please let me know if there are any questions. Thanks, Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907 - 777 -8395 1 • • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, May 15, 2013 8:45 AM To: 'Chad Helgeson' Cc: Luke Keller; Donna Ambruz Subject: RE: SCU 23A -09 P & A (PTD 200 -073) Chad, Don't resubmit the sundry, I will fill in the rotary rig procedure onto the P & A sundry for you this time... there are only a few steps missing. I agree with the 1 BBL of cement also.. that will be plenty ( that is quite a bit when dump bailing!) Thanks for the updated schematic. Guy Schwartz Senior Petroleum Engineer AOGCC 907 - 444 -3433 cell 907 - 793 -1226 office From: Chad Helgeson [ma ;Ito _h igest A k stir c:r =1,c_ >�f Sent: Wednesday, May 15, 2013 7:23 AM To: Schwartz, Guy L (DOA) Cc: Luke Keller; Donna Ambruz Subject: RE: SCU 23A -09 P & A (PTD 200 -073) Guy, Would you like me to resubmit the procedure with the Doyon sections of the work in this 403 procedure? I am sorry that I missed this. I knew better, but forgot to coordinate with Luke on his section of the procedure. 1. Attached is a new schematic, identifying a few more things and the CIBP and the tubing removed. 2. In step #12 on the procedure, I had planned to put in 1 bbl of cement (probably lost in some of the wording), which would give us 58ft of cement above the plug. This should be about 33ft of cement above the liner top and fill the tubing as you mentioned. Chad From: Schwartz, Guy L (DOA) [; l o :g =E,_ �c d `+ -- t �.. rS_: t.. 7. :.1 �K- !>.�.1 , i l l ii `/ Sent: Tuesday, May 14, 2013 11:49 AM To: Chad Helgeson Subject: SCU 23A -09 P & A (PTD 200 -073) Chad, On the P & A sundry (any P & A) make sure you include all steps including the Sidetrack operations up to and including setting a whipstock and milling window. The AOGCC does not consider the well abandoned till a window is cut. Also: 1)The schematic shows tubing in the wellbore and no CIBP at 9170' 2) not clear how much cement you are dumping on top of PX plug. My preference would be that it is above the packer 20 ft or so 10,070 would be good. 1 bbl cement should be good to get that much and also fill up the tubing down to PX. 1 • Guy Schwartz Senior Petroleum Engineer AOGCC 907 - 444 -3433 cell 907 - 793 -1226 office 2 • • Page l of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 V form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. original change ill inal well's status from 5. When the Form 10 -407 for the redrill is received, Steve M. will c g g suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily Document Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 ~ ~:~-~"":.. ",' '3.'-:¡"'.- "':, \" MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc - <!.-- :... ~ STATE OF ALASKA ~ AlA~ Oil AND GAS CONSERVATION COMM,- ..lION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon U Performed: Alter Casing D Change Approved Program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 135' KB 8. Property Designation: Swanson River Unit 11. Present Well Condition Summary: Suspend U RepairWeli D Pull TubingD Operation Shutdown U Perforate U Waiver D Plug Perforations D Stimulate D Time Extension D Perforate New Pool D Velocity string installation CANCELLED 4. Current Well Class: 5. Permit to Drill Number: Development D Exploratory D 200-073 Stratigraphic D Service 0 6. API Number: 50-133-10126-01 Other ~ 9. Well Name and Number: SCU 23A-09 10. Field/Pools(s): Swanson River FieldlHemlock Total Depth measured 10,960 feet true vertical 10,376 feet Effective Depth measured 10,936 feet true vertical 10,381 feet Plugs (measured) Junk (measured) Casing Length Size MD TVD Structural Conductor 32' 20' 32' 32' Surface 2,009' 11-3/4" 2,009' 2,009' Intermediate Production 10,192' 7" 10,192' 10,191' Liner Burst Collapse 6,340 psi 3,830 psi Perforation depth: Measured depth: 10,150 to 10,168' RECEIVED "'-OS ~:11)~~4 ~~ ZXP liner top packer wI 6' x 5.25" ID tieback sleeve @ 10,095. 3-1/2", L-80 @ 10,130 True Vertical depth: 10,148 to 10,167' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): nla job cancelled Treatment descriptions including volumes used and final pressure: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met I Water-Bbl I Casing Pressure Tubing Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run nla Exploratory D Development 0 Daily Report of Well Operations nla 16. Well St~~, after pr~posed work: Oil~ fr' Gas r J WAG D GINJ D WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my nowledge. SUndry Number or NIA if C.O. Exempt: Contact Steve Tyler 907-263-7649 nla no production prior to operations and work cancelled. Service D Printed Name Philip J. Krueger Title Drilling Manager Signature y~ / h.r Form 10~4 Revised 12/2003 Phone 907-276-7600 Date 4/27/2004 RBDMS BFl MAY 0.3 2000 RIG I N A l SIZE WT 20" 11-3/4" 47 7" 29 7" 26 7" 23 ?" 26 7" 29 ~ . - UNOCAL8 RKB = 18.85' 1 2 3 3-112" liner slotted Tubing 3-112" 4 9.3 24 slots/ft 9.3 0 DV Collar @ NO. Depth 6796' I 18.85' 44' 2 3 2500' 4 , , , ", G2 "" HI --- " ", H2 " ", H3 ~ """'", "" - - ~- - - - - - - - - - - - - - -- - - - -- - -- - -- - - - - - - -~ -_I!~ - - - - - - -- -- _I ""',,----~------------------------------------------------ 5 6a 4a 6b 7 Gl ~ =10150'-10168' , , , \ \- Top of \ window , ' ,- @ 10192' 8 9 L. SCD 23A-9 7-11-00 Schematic Drawn by: TAB 4a 5 2604' 4599' 6388' 7809' 8642' 9452' 10051 ' lOBO' 10095' 10110' 10117' 10133' 6a 6b 7 8 9 10 lOBO' 10195' 10216' 10935' ID 2.992 2.867 2.867 2.992 5.25 4.438 4.000 3.437 2.813 2.992 r'""\ wanson River Well SCU 23A-9 As Completed 7/11/00 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 32' 2009' 288' 1048' 4715' 6543' 10192' Window 8rd 11.000 Surface N-80 Buttress 6.184 Surface N-80 Buttress 6.276 288' N-80 Buttress 6.366 1048' N-80 Buttress 6.276 4705' N-80/PllO Buttress &8rd 6.184 6543' J-55 1/8" wide Hydril511 2.5" long 10935' 2.992 12 slots/row 10095' L-80 8rd 2.992 lOBO' Surf JEWELRY DETAIL OD Item Tubing Hanger, 7-1116" x 3-112" Butt., Type" H" BPV profile. CL prep. WI 3-1/2" SC buttress space out pups Xover, 3-112" buttressx Srd 3.500 3-112" N-SO 9.2 ftIlb Srd. tubing 5.500 Methanol Injection Mandrel Macco SFO-ICI with 3/S" control line strapped wll6S xl-1I4" SS bands 5.313 Macco SFO-I GLMs, BK-2Iatches, R-I valves GLM #1 GLM #2 GLM #3 GLM #4 GLM #5 GLM #6 GLM #7 orifice Tubing Seals, 13' long x 4.000" OD w/4.125" locater ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve Baker HMC liner hanger Seal Bore Extension KOIV flapper, 3.437" ID after flapper knocked out on 7/18/00 with slickline weight bar. 4.000 Baker X nipple, 2.813" ID Baker Bottom Trip Whipstock 7" retainer 3-112" liner shoe 4.000 5.75 5.875 5.625 5.500 3.5 TD = 10,960' MD/I0,376' TVD MAX HOLE ANGLE = 95 deg 04/27/04 STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPOR I OF SUNDRY WELL OPERA liONS 1. Operations Abandon U Performed: Alter Casing D Change Approved Program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 135' KB 8. Property Designation: Swanson River Unit 11. Present Well Condition Summary: Suspend U Repair Well D Pull Tubing D Total Depth measured 10,960 true vertical 10,376 Effective Depth measured 10,936 true vertical 10,381 Other ~ Operation Shutdown U Perforate U Waiver D Plug Perforations D Stimulate D Time Extension D Perforate New Pool D Velocity string installation CANCELLED 4. Current Well Class: 5. Permit to Drill Number: Development D Exploratory D 200-073 Stratigraphic D Service D 6. API Number: 50-133-10126-01 9. Well Name and Number: SCU 23A-09 10. Field/Pools(s): Swanson River Field/Hemlock feet feet Plugs (measured) Junk (measured) feet feet Burst Collapse Casln9 Struc;tural Conductor Surface Intermediate Production Liner Length Size MD TVD 32' 20' 32' 32' 2,009' 11-3/4" 2,009' 2,009' 10,192' 7" 10,192' 10,191' Perforation depth: Measured depth: 10,150 to 10,168' True Vertical depth: 10,148 to 10,167' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): nla job cancelled Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run nla Daily Report of Well Operations nla 6,340 psi 3,830 pSI 3-112", L-<lO @ 10,130 F?€CElI/€D APR ~ Je ZXP liner top packer wI 6' x 5.25" ID tieback slee~0,095. .9& 20(1 011. G,., ,,4 ~.~ Representative Daily Average Production or Injection Data Gas-Met I Water-Bbl I Casing Pressure nla no production prior to operations and work cancelled. Tubing Pressure 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: oilD Gas 0 WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 907-263-7649 Printed Name Philip J. Krueger Signature y~ / h.r Form 104b4 Revised 12/2003 Service D GINJ D WINJ D WDSPL D ISUndry Number or NIA if C.O. Exempt: Title Drilling Manager Phone 907-276-7600 Date 4/27/2004 DUPLICp\TE r--\ . - '. UNOCAL8 RKB = 18.85' SIZE 20" 11-314" 7" 7" 7" 7" 1 2 7" 3 3-112" liner slotted Tubing 3-1/2" 5 6a 4a 4 47 29 26 23 26 29 9.3 24 slots/ft 9.3 0 DV Collar @ NO. Depth 6796' I 18.85' 44' 2 3 2500' 4 Gl ~ =10150'-10168' \ \ , , '.- Top of '. window '-- @ 10192' , , ", G2 , "" HI " ',"2 " "" H3 , """'""",,"" --,- -- - -- - -- -u _u_, - - u - --- - - - - -- - - -~ -_I!~ --- - - - - - - - ) "-, I ---------------------------------------------------- 6b 7 8 L. SCU 23A-9 7-11-00 Schematic Drawn by: TAB 4a 5 2604' 4599' 6388' 7809' 8642' 9452' 10051 ' 10130' 10095' 10110' 10117' 10133' 6a 6b 7 8 9 10 lOBO' 10195' 10216' 10935' WT ID 2.992 2.867 2.867 2.992 5.25 4.438 4.000 3.437 2.813 2.992 ~anson River n' ell SCU 23A-9 As Completed 7/11/00 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 32' 2009' 2SS' 1048' 4715' 6543' 10192' Window Srd 11.000 Surface N-SO Buttress 6.184 Surface N-SO Buttress 6.276 288' N-SO Buttress 6.366 1O4S' N-80 Buttress 6.276 4705' N-80/PllO Buttress &Srd 6.184 6543' J-55 liS" wide Hydril511 2.5" long 2.992 12 slots/row 10095' 10935' L-80 Surf 10130' 8rd 2.992 JEWELRY DETAIL OD Item Tubing Hanger, 7-1/16" x 3-1/2" Butt., Type" H" BPV profile. CL prep. WI 3-1/2" SC buttress space out pups Xover, 3-1/2" buttressx 8rd 3.500 3-112" N-80 9.2 ftllb 8rd. tubing 5.500 Methanol Injection Mandrel Macco SFO-I CI with 3/8" control line strapped wl168 xl-1/4" SS bands 5.313 Macco SFO-I GLMs, BK-2Iatches, R-I valves GLM#I GLM #2 GLM #3 GLM #4 GLM #5 GLM #6 GLM #7 orifice Tubing Seals, 13' long x 4.000" OD w/4.125" locater ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve Baker HMC liner hanger Seal Bore Extension KOIV flapper, 3.437" ID after flapper knocked out on 7/18/00 with slickline weight bar. 4.000 Baker X nipple, 2.813" ID Baker Bottom Trip Whipstock 7" retainer 3-112" liner shoe 4.000 5.75 5.875 5.625 5.500 3.5 TD = 10,960' MD/I0,376' TVD MAX HOLE ANGLE = 95 deg 04/27/04 ~. STATE OF ALASKA ~ ALAS.v'\ OIL AND GAS CONSERVATION COMMk ..lION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: # Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 135' KB 8. Property Designation: Swanson River Unit 1. Type of Request: 11. Total Depth MD (ft): 10,960' Casing Structural Total Depth TVD (ft): 10,376' Length Conductor Surface 32' 2,009' Intermediate Production 10,192 Liner Perforation Depth MD (ft): 10,150 to 10,168 Packers and SSSV Type: Perforate U ¡J6k Waiver U Annular Dispos. U Stimulat~ Time Extension D Oth~r [Ø" ~ Re-enter Suspended Well D ~t.~l út'loc,¿~ 5. Permit to Drill Number: \ 200-073 / 6. API Number: Suspend U Repairwell D Pull Tubing D Development Stratigraphic ~ 0 Exploratory D Service 0 9. Well Name and Number: SCU 23A-09 / 10. Field/Pools(s): Swanson River Field/Hemlock PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 10,935 10,381 Plugs (measured): Size MD 20" 32' 11-3/4" 2,009' 7" 10192' TVD 32' 2,009' 10191' Perforation Depth TVD (ft): 10,148 to 10,167 Tubing Size: 3-1/2" Tubing Grade: L-80 ZXP Liner Top PKR wI 6' x 5.25" ID tieback Packers and SSSV MD (ft): sleeve. 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program D BOP Sketch D 14. Estimated Date for 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Philip J. Krueger Title Drilling Manager Signature ~ ¡í1a _Phone 907-276-7600 Date 7 .. 6-- COMMISSION USE ONLY Commencing Operations: 5/30/2004 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil D Gas 0./ Plugged WAG D GINJ D WINJ Date: 7>~ 4Ì 2..(( 1-- 50-133-10126-01 /' Junk (measured): Burst Collapse 532 psi 3,830 psi Tubing MD (ft): 10,130 10,095' 0/ Service D D Abandoned D D WDSPL D Contact Steve Tyler 907-263-7649 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test D Other: Approved by: Alaska Oil & Gas Cons. Commission Anchorage D~ sf:i~f Mechanical Integrity Test D D Location Clearance R8DUS 8Ft ø 2- 8 .. ORIGINAL BY ORDER OF THE COMMISSION COMMISSIONER INSTRUCTIONS ON REVERSE 4/16/2004 30 tj..j50 J RECEIVED APR 2 3 2004 Gl " =10150'-10168' \ \ , \ \ Top of \- .. window '-- @ 10192' , , , ", G2 "" HI " "H2 " "" H3 ""'- .. H5 """""""--~~~~~~~~~~~~~~~~~~~~~~~~~~~~] ~ UNOCALfj RKB = 18.85' SIZE WT 20" 11-3/4" 47 7" 29 7" 26 7" 23 7" 26 7" 29 1 2 3 3-112" liner slotted Tubing 3-112" 9.3 9.3 24 slots/ft 5 6a 4a 2604' 4599' 6388' 7809' 8642' 9452' 10051 ' 10130' 10095' 10110' 10117' 10133' 0 DV Collar @ NO. Depth 6796' I 18.85' 44' 2 3 2500' 4 6b 7 4a 5 8 7 8 9 10 10130' 10195' 10216' 10935' 6a 6b 9 ~ L. ~ ID 2.992 2.867 2.867 2.992 5.25 4.438 4.000 3.437 2.813 2.992 r'""\ . .vanson River Well SCU 23A-9 As Completed 7/11/00 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 32' 2009' 288' 1048' 4715' 6543' 10192' Window 8rd 11.000 Surface N-80 Buttress 6.184 Surface N-80 Buttress 6.276 288' N-80 Buttress 6.366 1048' N-80 Buttress 6.276 4705' N-80/P II 0 Buttress &8rd 6.184 6543' J-55 118" wide Hydril 511 2.5" long 2.992 12 slots/row 10095' 10935' L-80 8rd 10130' 2.992 Surf JEWELRY DETAIL OD Item Tubing Hanger, 7-1116" x 3-112" Butt., Type" H" BPV profile. CL prep. WI 3-112" SC buttress space out pups Xover, 3-1/2" buttressx 8rd 3.500 3-1/2" N-80 9.2 ft/lb 8rd. tubing 5.500 Methanol Injection Mandrel Macco SFO-ICI with 3/8" control line strapped w/168 xl-1I4" SS bands 5.313 Macco SFO-I GLMs, BK-2Iatches, R-I valves GLM #1 GLM #2 GLM #3 GLM #4 GLM #5 GLM #6 GLM #7 orifice Tubing Seals, 13' long x 4.000" OD w/4. I 25" locater ZXP Liner Top Pkr with 6' x 5.25" 1D tieback sleeve Baker HMC liner hanger Seal Bore ExtensIOn KOIV flapper, 3.437" ID after flapper knocked out on 7/18/00 with slickline weight bar. 4.000 Baker X nipple, 2.813" ID Baker Bottom Trip Whipstock 7" retainer 3-112" liner shoe 4.000 5.75 5.875 5.625 5.500 3.5 TD = 10,960' MD/I0,376' TVD MAX HOLE ANGLE = 95 deg SCU 23A-9 7-11-00 Schematic Drawn by: TAB 04/13/04 ~ ....-.... Swanson River Well SeD 23A-9 UNOCAL8 Proposed Velocity String Completion ~ uM~ri~J ~ SuJlWriZed Procedure . MIRU Slickline. RIH wi GR to 10,450'. POOH. RD. . MIRU 1-3/4" CTU. NU BOPE, MU CTC. Pressure test same. . PUMU Lwr BHA. RIH wi 1-3/4" CT to 10,400'. / . Cut CT MU CTC & TIW Hanger. RIH on GS PT. hang CT below tbg hngr. / . Release from CT Hngr. POOH. Secure well. RD Demobe CTU. . ND tree and flowlines above bottom master valve. . NU 2-1116" flow tee, CT hngr, master valve, flow tee and swab valve. / I IlL 1. r e£J1? ~ . RU Slickline. PUMU Tie-Back assy. RIB stab seal assy into hngr tie-back r~le. Land in CT hangr . . Turn well over to production. / seD 23A-09 Proposed Vel Strng Schematic Drawn by: SL T 4/5/2004 Permit to Drill 2000730 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. SOLDOTNA CK UNIT 23A-09 Operator UNION OIL CO OF CALIFORNIA APl No. 50-133-10126-01-00 MD 10960 -I-VD 10376 Completion Dat 7112/2000 Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N._9o Sample N._9o Directional Survey ~.,,,~-0''''~'~') .~'"' DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Name Scale Media No Start Stop CH Received Number Comments 10180 10810 Open 8/30/2000 09703 10180-10810 GR-TVD 2/5 1-5 10200 10380 OH 8/30/2000 GR-MD 2/5 1-5 101800 10910 OH 8/30/2000 SRVY RPT 10115 10960 OH 8/30/2000 9703 1 OH 8/30/2000 97O3 10200-10380 7/1/00 THRU 101800-10910 7/1/00 THRU SCHLUM 10115-10960 SCHLUM BHP Well Cores/Samples Information: Name Interval Dataset Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~) Chips Re ce ive d ?----Y--?N---~ Analysis R ~.c.~.ivP. d ? Daily History Received? '~/N Formation Tops ~.~ N Comments: Compliance Reviewed By: Date: Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99519-6247 Tele: (907) 263-7889 Fax: (907) 263-7828 E-marl: childersd @ unocal, com UNOCAL ) Debra Childers Geotech Assistant DATA TRANSMITTAL August: 29, 2000 To: Lori Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: Well LOG ~PE SCALE LOG DATE INTERVAL COPIE Medium SCU~14-3 Thermal Decay Tool/Sigma Logs 2/5 INCH 7/22/003400-8200 1 B-Line SCU34-3 Thermal Decay Tool/Sigma Logs 2/5 INCH 7/22/003400-8200 1 Film SCU 23A-9 MWD GR Measured Depth Log 2/5 INCH 7/1/00 10180-10910 1 B-Line SCU 23A-9 MWD GR Measured Depth Log 2/5 INCH 7/1/00 10180-10910 1 Film SCU 23A-9 MW_D GR True Vertical Depth Log 2/5 INCH 7/1/00 10180-10910 1 B-Line SCU 23A-9 MWD GR True Vertical Depth Log 2/5 INCH 7/1/00 10180-10910 1 Film SCU 323-9 Plug Setting Record 5 INCH 6/24/009900-10240 1 B-Line SCU 323-9 Plug Setting Record 5 INCH 6/24/009900-10240 1 Film SCU 42-4 Cement Bond Log / Gamma Ray-CCL 5 INCH 7/24/008000-10190 1 B-Line SCU 42-4 Cement Bond Log / Gamma Ray-CCL 5 INCH 7/24/008000-10190 1 Film SCU 42-4 MWD GR Measured Depth Log 2/5 INCH 7/27/0010165-10845 1 B-Line SCU 424 MWD GR Measured Depth Log 2/5 INCH 7/27/0010165-10845 1 Film s,.CU 42-4 MWD GR True Vertical Depth Log 2/5 INCH 7/27/0010165-10845 1 B-Line SCU 42-4 MWD GR True Vertical Depth Log 2/5 INCH 7/27/0010165-10845 1 Film SCU 42-4 Plug Setting Record 5 INCH 7/24/008000-10190 1 B-Line SCU 42-4 Plug Setting Record 5 INCH 7/24/008000-10190 1 Film Please acknowl~g,dng and returning one copy of this transmittal or F,I~( ~ ~)~-~ l Received L~-~~~~ I Date: ]~U(~ ~0 ~000 J Alaska Oil & Gas Cons. Commission Anchorage Re: SCU 23A-9 BOP test pressure Subject: Re: SCU 23A-9 BOP test pressure Date: Tue, 23 May 2000 10:04:41 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "Billingsley, Tim-Contract" <billita@unocal.com> Thanks Tim. Please note the initial test is all that need be 5000. Any subsequent tests on 23A-9 need only be to 3000. Thanks again. Tom "Billingsley, Tim -Contract" wrote: > As per our conversation, the BOP test on SCU 23A-9 (formerly S.C_..U 323-9) will > be to 5000 psi. Since this is the first well after a long down time, the.-'~- > full test to the 5000 psi pressure rating of the stack will be done. > The following well, SCU 341-4, can be tested to only 3000 psi. > Thanks, > > Tim Billingsley > 263-7659 Tom Maunder <tom maunder~admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 5/23/00 10:17 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well O~ GAS: X SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) 200-073 3. Address 8. APl Number P. O. Box 196247, Anchorage, Ak 99519 50- 133-10126-01 4. Location of well at surface ~- .......................... ~ ~ 9. Unit or Lease Name 2520' FSL, 1970' FWL, Sec. 9, T7N, R9W, SM ; .........._._~ ,'~ ¢~ ~:1"¢'JI"~4~"~" Soldotna Creek Unit AtTop Producing Interval (10280' MD top of Hemlock) i-, £;¢~'~[: ' '1 ~, ti- 10. Well Number 2594' FSL, 1642' FWL, Sec. 9, TTN, R9W, SM ¢ ............... ~~i SCU #23A-9 At Total Depth 10,960' MD ~Z~~=__ 11. Field and Pool 2678' FSL, 1008' FWL, Sec. 9, T7N, R9W, SM ~ .............. 5. Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease Designation and Serial No. Swanson River Fiel~Hemlock 135' KB~ A-028997 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ~ 15. Water Depth, if offshore ~ 16. No. of Completions 6/30/00 7/7/00 7/1~00~ NA feet MSL~ 1 17. Total Depth(MD+TV D)10960, MD/10376' TVD 18. Plug Back Depth (MD+TVD)10960, ~w I'°'~'~"°"~'s"~' I 22. Type Bectric or Other ko~s ~un kWD Oamma GASI~G SIZE ~. ~ ~. G~Dfi TO~ BOTTOM 20" 0 ~2' Driven 0 11-~/4" 47~ ~-5~ 0 200~' 17-~/2" 1800 sx 0 7" 2~, 2~, 2~ ~-80 0 ~0~2' ~-7/8" ~00 sx 0 ~- 1/2" ~.2~ 0-~ ~ 00~' ~ 0~' ~" ~ono 0 24. ~e~orations open to ~roduction (M~TV~ o[ Top and BoSom and 25. TOBI~ BfiGO~D inte~al, size and number) SIZfi Dfi~TH S~ (MD) ~AOKfiB S~ (MD) ~- ~/2" ~ 01 g0' ~ 00~$' Slotted liner from 10228' - 10~8~' M D/10220'- 10g75'TVD 27. ~BO~GTIO~ Dato First ~roduction I Method o[ Operation {Flowing, ~ao li~, etc.) 7/20/2000 lfiowin~ to production Dato o[ Tost Hours Testod ~BOD~GTIO~ FOB OIk-BBk GAS-~GF 8/~00 24 T~ST ~fi~lO~ => 2 ~710 MGF ~ 2 10164~ ~,~,000 Flow Tubin~ Oasin~ ~rossum GAk~O~T[D OIk-BBk GAS-M~F WATfi~-BBk OIk O~VIIY-~I (tort) ?ross. ~080 1140 24-HOH~ ~Tfi ~> 2 ~710 MGF 28. CORE DATA Brief de~ription of lithology, porosi~, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL .,-.. :.¢.,~, , r':: . . , Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate .. - 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Hemlock Formation 10,280 10,270 Top Hemlock HB-5 10505 10373 31. LIST OF ATTACHMENTS Wellbore schematic, Daily Summary of Rig Operations, Directional Survey Record 32. I hereby.9.e,~tify that the foreaoing is true ~and correct to the best of my knowledge Signe .~ Title Drillinq Manager Date Form 10-407 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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 space 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 productin 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". UNOCAL RKB = 18.85' SIZE 20" 11-3/4" 7" 7" 7" 7" 7" WT ~vanson River Well SCU 23A-9 As Completed 7/11/00 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 47 29 26 23 26 29 8rd N-80 Buttress N-80 Buttress N-80 Buttress N-80 Buttress N-80/P110 Buttress &8rd 32' 11.000 Surface 2009' 6.184 Surface 288' 6.276 288' 1048' 6.366 1048' 4715' 6.276 4705' 6543' 6.184 6543' 10192' Window 3-1/2" liner 9.3 J-55 Hydril 511 slotted 24 slots/ft 1/8" wide 2.5" long Tubing 3-1/2" 9.3 L-80 8rd 2.992 10095' 10935' 12 slots/row 2.992 Surf 10130' 5 6a 6b DV Collar @ 6796' 4a NO. 1 2 3 4a G1 _1__10150'-10168' 6a Top of 6b window 7 98 ",. G2 10 '%. HI H2 "' ItS Depth 18.85' 44' 2500' 2604' 4599' 6388' 7809' 8642' 9452' 10051' 10130' 10095' 10110' 10117' 10133' ID 2.992 2.867 JEWELRY DETAIL OD Item 3.500 5.500 2.867 5.313 2.992 4.000 5.25 5.75 4.438 5.875 4.000 5.625 3.437 5.500 10130' 2.813 4.000 10195' 10216' 10935' 2.992 3.5 Tubing Hanger, 7-1/16" x 3-1/2" Butt., Type" H" BPV profile. CL prep. W/3-1/2" SC buttress space out pups Xover, 3-1/2" buttress x 8rd 3-1/2" N-80 9.2 ft/lb 8rd. tubing Methanol Injection Mandrel Macco SFO-1CI with 3/8" control line strapped w/168 x 1-1/4" SS bands Macco SFO-1 GLMs, BK-2 latches, R-I valves GLM #1 GLM #2 GLM #3 GLM #4 GLM #5 GLM #6 GLM #7 orifice Tubing Seals, 13' long x 4.000" OD w/4.125" locater ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve Baker HMC liner hanger Seal Bore Extension KOIV flapper, 3.437" ID after flapper knocked out on 7/18/00 with slickline weight bar. Baker X nipple, 2.813" ID Baker Bottom Trip Whipstock 7" retainer 3-1/2" liner shoe ~ H5 I TD = 10,960' MD/10,376' TVD MAX HOLE ANGLE = 95 deg SCU 23A-9 7-11-00 Schematic.doc Drawn by: TAB 08/08/00 UNOCAL Alaska Drilling Drilling Summary Report SCU #323-9 Abandonment & SCU 23A-9 Redrill 6/1/00 to 7/13/00 6/1/00 Pump 65 bbl water in tubing to kill well, tbg pressure fell from 1420 psi to vacuum. RU APRS. Set 2-7/8" bridge plug at 10,600'. Punch tubing with 8 holes from 10,437'-10,439'. Set 2-7/8" cement retainer at 10,400'. RD APRS. 6/2/00 RU coil tubing unit. RIH with 1-3/4" coil and stinger with 6' of 1-3/4" straight bar. Could not penetrate SC-2P packer top at 10,260' ctm. POOH. 6/3/00 Add 2-1/8" weight bars to eliminate coil memory problems. RIH and still could not pass through packer top at 10,260'. POOH. RU slickline and RIH with CT BHA, small bobble at 10,258' wlm but able to pass through to retainer at 10,406' wlm. POOH. 6/4/00 Add one jt of 1-1/4' CS Hydril tubing to coil tubing BHA and round off stinger. RIH and made it through packer at 10,260' with no problem. Sting into retainer at 10,406'. Establish injection rate of 2.5 BPM at 1520 psi. Mix and pump 14.5 bbl of 15.8 ppg cement at 2 to 1.4 bpm and 2800 psi. Unsting and lay in last 0.8 bbl of cement on top of retainer while POH to 10,100'. Circ coil clean. POOH and RD CTU. 6/7/00 RU slickline. RIH with 2.25" gauge ring. Tag top of cement at 10,390' wlm. Pull gas lift valve from lowest GLM at 9934'. RD slickline. 6/8/00 Pump 220 bbl water into tubing, no returns seen on annulus. Shut down. No further work on well until Permit to Drill approved and rig moves on well. 6/14-18/00 Turn-key rig move from SCU 22-4 location to 323-9. 6/19-21/00 ND tree, NU BOPE. Repair choke manifold, general rig up. UNOCAL Alaska Drilling Weekly Drilling Summary Report SCU #323-9 Abandonment and SCU #23A-9 Redrill 6/22/00 6/23/00 6/24/00 6~25~OO 6/26/00 6/27/00 6/28/00 6/29/00 6/30/00 7/1/00 7/2/00 Test BOPE to 250 psi/4200 psi witnessed by Bo Brown-BLM. (Initial BOPE test to 5000 psi was reduced to 4200 psi as per Bo Brown-BLM and Blair WondzelI-AOGCC). Engage tubing hanger and pull FH packer at 9987' free with 94K pull. Circ until well stable. Lay down tubing and packer. RU Schlumberger. Set 7" retainer at 10,216' elm. RIH with cement stinger on 3-1/2" drill pipe. Stab in to retainer at 10,214' dpm. Perform injectivity test at 2.6 BPM @ 1900 psi. Decide to increase cmt volume from 20 bbls to 30 bbls due to good injectivity. Mix and pump 30 bbls of 15.8 ppg cement with pressure increasing from 1800 psi to 2500 psi at 2.8 bpm, left 5 bbl cmt on top of retainer. Unsting and POH 10 stands. Circ drill pipe clean with no cmt returns. POOH with drill pipe. RIH with two 6"mills. Clean up tight spots at 5775' and 6236'. Tag cement at 10,155', drill firm cement from 10,155' to top of retainer at 10,214' dpm. Circ hole clean. Change over well from water to 8.4 ppg oil-based mud. POH with mills, observed 20k overpull at 6237'. Rotate and work pipe up to 5700' and back down to 6250' with no further signs of overpull. POOH and lay down mills. RIH with whipstock milling assembly to 10198'. RU Schlumberger and Gryrodata. RIH with gyro on E-line and orient whipstock face to 284 deg. POOH and RD wireline. Set down with whipstock on retainer at 10214' to set anchor. Shear off bolt with 35k down. Start milling window at 10,192'. Mill window from 10192' to 10216' with 8.4 ppg mud. POOH with mills. Test BOPE to 3000 psi, witness waived by AOGCC and BLM. RIH with 6" Bit #1 on 3.06° Short-Pac motor. RU side entry sub and gyro on E- line. Drill from 10216' to 10306'. Pull Gyro and RD E-line. Continue drilling with MWD to 10418' with 8.4 ppg mud. Circ BU and POOH for new bit and BHA. RIH with Ultraslow motor at 1.5© ABH. Slide drill from 10418' to 10432' with 8.4 ppg mud, UNOCAL Alaska Drilling Weekly Drilling Summary Report SCU #23A-9 Redrill 7/3/00 7/4/00 7/5/O0 7/6/00 7/7/00 7/8/00 7/9/OO Slide drill from 10432' to 10487'. Rotary drill from 10487' to 10505', slide drill from 10505' to 10633'. Circ sweep and POOH with bit #2. MW=8.5 ppg. Pulled tite with 25k overpull at 10550' and 10417' to 10394'. RIH with Bit #3 and rotary drill from 10633' to 10685'. MW=8.4 ppg. Drill from 10685' to 10749', ROP dropped. MW = 8.4 ppg. POOH with Bit #3, no hole problems. RIH with Bit #4. Drill from 10749' to 10894'. MW=8.4 ppg. POOH with bit #4. RIH with Bit #5, Drill from 10894' to 10960' TD with 8.5 ppg mud. Penetrated coal at 10947'-10960', called TD early due to coal being 13' TVD higher than expected. Circ hi-vis sweep with bit at 10935'. Recovered 2 bbls of coal, POOH with no problems. AOGCC-Lou Grimaldi waived BOP test due to running liner. RIH with 3-1/2" slotted liner and 2-1/16" inner string to 10935'. Drop ball and set hanger at 1200 psi, attempt to pressure up to release running tool up to 3000 psi, no release. Blow ball at 3750 psi. Left hand turn to release running tool. Displace open hole and 3-1/2" slotted liner with 40 bbls base oil. Set ZXP liner top packer with 50k down weight. Test packer and casing to 1520 psi, good test. POOH with inner string to top of liner. Change over well from 8.5 ppg mud to 7.4 ppg base oil. POOH laying down drill pipe. UNOCAL Alaska Drilling Weekly Drilling Summary Report SCU #23A-9 Redrill 7/10/00 Finish laying down drill pipe and inner string. Run 3-1/2" tubing completion with GLMs and methanol injection mandrel. 7/11/00 Stab seals with landing joint, test tubing against Knock-out Isolation Valve to 500 psi, good test. Space out and land hanger, could not test at Iow rate (tubing circulated to annulus). Retest with higher flow rate and able to test tubing to 500 psi. (Gas lift check valves apparently did not close at Iow rate but did close at higher flow rate). 7/12/00 ND BOPE, NU tree. Clean rig in preparation for move to SCU 42- 4. 7/13/00 Release rig from SCU 23A-9 on 7/13/00 at 02:30 am. Start move to SCU 42-4. 7/14-16 RU flowlines and gas lift lines in preparation to flow SCU 23A-9. ANADRILL SCHLUMBERGER Survey report. Client ...................... ;UNOCAL Field ...................... ; Swanson River Well ..................... : SCU ~23A-9 API number ............... : 50-133-10126-01 Engineer ................... : Leafstedt Rig: ..................... : CC #1 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Driller's Pipe Tally GL above permanent ....... : 116o00 ft KB above permanent ....... : 135.00 ft DF above permanent ....... : 135o00 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ ~ -999.25 ft Azimuth from rotary table to target: 277.10 degrees 8-Jul-2000 15:09:03 Page ORIGINAL Spud date ................ : 1961 Last survey date ......... : 07-Jul-00 Total accepted surveys..°: 27 MD of first survey ....... : 10115°00 ft MD of last survey ........ : 10960°00 ft 1 of 2 Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 00-Y- 0 Magnetic field strength..: 1105.80 HCNT Magnetic dec (+E/W-) ..... : 21.44 degrees Magnetic dip ............. : 73.54 degrees MWD survey Reference Criteria Reference G .............. : 1002.02 mGal Reference H .............. : 1105.80 HCNT Reference Dip ............ : 73.55 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 21.44 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 21.44 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6_iA_21] RECEIVED AU6,3 0 Alaska Oil & Gas Cc,~m. ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 10115.00 1.50 304.09 2 10205.50 3.60 297.40 3 10239.00 11.50 264.10 4 10260.00 18.90 267.50 5 10276.48 22.58 280.17 6 10303.31 32.14 278.49 7 10333.01 44.26 272.91 8 10362.60 56o16 269.63 9 10387.42 64.94 271.79 10 10411.99 74.27 271.23 11 10438.42 76.75 273.63 12 10474.10 78.19 276.84 13 10501.44 78.48 276.41 14 10532.46 82.19 276.79 15 10565.27 85.71 277.67 16 10584.84 88.42 278.41 17 10627.76 93.36 279.61 18 10690.74 93.68 279.57 19 10728.80 95.50 279.15 20 10755.00 94.09 279.47 0.00 90.50 33.50 21.00 16.48 26.83 29.70 29.59 24.82 24.57 26.43 35.68 27.34 31.02 32.81 TVD depth (ft) 8-Jul-2000 15:09:03 Page 2 of 2 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) i00f) type type 10107.00 313.63 72.52 10197.41 317.35 74.49 10230.60 321.60 74.63 10250.85 327.00 74.27 10266.27 332.80 74.71 10290.07 345.10 76.68 10313.37 363.41 78.38 10332.28 385.98 78.82 10344.47 407.43 79.11 10353.03 430.33 79.71 -307.02 -310.52 -314.79 -320.28 -326°06 -338.22 -356.46 -379.14 -400.73 -423.73 -449.29 -483.97 -510.56 -540.93 -573.30 10359.64 455.83 80.80 10367.38 490.64 83.98 10372.91 517.41 87.07 10378.12 547.98 90.58 10381.57 580.60 94.69 315.47 283.29 0.00 TIP 319.33 '283.49 2.34 GYR 323.51 283.34 26.02 GYR 328.77 283.06 35.48 GYR 334.51 282.91 35.09 SP 346.80 282.77 35.75 SP 364.97 282.40 42.39 SP 387.25 281.74 41.10 SP 408.46 281.17 36.17 SP 431.16 280.65 38.03 SP 456.50 280.20 12.86 SP 491.20 279.84 9.67 SP 517.93 279.68 1.87 SP 548.47 279.51 12.02 SP 581.06 279.38 11.06 SP 19.57 10382.58 600.14 97.42 -592.65 600.60 42.92 10381.91 643.02 104.14 -635.02 643.50 62.98 10378.04 705.82 114.61 -697.00 706.36 38.06 10375.00 743.73 120.78 -734.43 744.30 26.20 10372.81 769.82 125.01 -760.20 770.41 279.34 14.35 SP 279.31 11.84 SP 279.34 0.51 SP 279.34 4.88 SP 279.34 5.48 SP 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 21 10788.20 91.85 280.04 22 10821.56 89.07 279.17 23 10836.94 88.39 278.95 24 10864.19 88.15 279.46 25 10893.45 87.91 278.79 26 10906.13 87.67 278.74 Projected To TD 27 10960.00 86.70 278.55 33.20 10371.09 802.94 130.63 33.36 10370.83 836.26 136.19 15.38 10371.17 851.63 138.61 27.25 10371.99 878.85 142.97 29.26 10373.00 908.07 147.61 -792.87 -825.76 -840°94 -867.83 -896.70 803.56 279.36 6.96 SP 836.91 279.37 8.73 SP 852.29 279.36 4.65 SP 879.53 279.36 2.07 SP 908.77 279.35 2.43 SP 12.68 10373.48 920.74 149.54 -909.22 921.44 53.87 10376.13 974.52 157.63 -962.42 975.24 279.34 1.93 SP 279.30 1.83 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [ (c)2000 Anadrill IDEAL ID6_iA_21] RECEIVED AUG 30 2000 Oil & 6~:¢ C.~n~. g~': mmiss~o~' ANADRILL SCHLUMBERGER Survey report Client .................... : UNOCAL Field .................... : Swanson River Well ..................... : SCU #23A-9 API number ............... : 50-133-10126-01 Engineer ................... : Leafstedt Rig: ...................... : CC #1 STATE: ................... : Alaska Survey calculation methods Method .for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Driller's Pipe Tally GL above permanent ....... : 116.00 ft KB above permanent ....... : 135.00 ft DF above permanent ....... : 135o00 ft Vertical section origin Latitude (+N/S-) ......... Departure (+E/W-) ........ 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 277.10 degrees 8-Jul-2000 15:09:03 Page 1 of 2 DUPLICATE Spud date ................ : 1961 Last survey date ......... : 07-Jul-00 Total accepted surveys..°: 27 MD of first survey ....... : 10115.00 ft MD of last survey ........ : 10960.00 ft Geomagnetic data ......... Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 00-Y- 0 Magnetic field strength..: 1105.80 HCNT Magnetic dec (+E/W-) ..... : 21.44 degrees Magnetic dip ............. : 73.54 degrees MWD survey Reference Criteria .......... Reference G .............. : 1002.02 mGal Reference H .............. : 1105.80 HCNT Reference Dip ............ : 73.55 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections ............... Magnetic dec (+E/W-) ..... : 21.44 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 21.44 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6_iA_21] RECEIVED AUG ,"vo Co~.rr, dssior' A.r, ohO 'sge ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 1 10115.00 1,50 304.09 2 10205.50 3.60 297.40 3 10239.00 11.50 264.10 4 10260.00 18.90 267.50 5 10276.48 22.58 280.17 6 10303.31 32.14 278.49 7 10333.01 44.26 272.91 8 10362.60 56.16 269.63 9 10387.42 64.94 271.79 10 10411.99 74.27 271.23 11 10438.42 76.75 273.63 12 10474.10 78.19 276.84 13 10501.44 78.48 276.41 14 10532.46 82.19 276.79 15 10565.27 85.71 277.67 16 10584.84 88.42 278.41 17 10627.76 93.36 279.61 18 10690.74 93.68 279.57 19 10728.80 95.50 279.15 20 10755.00 94.09 279.47 21 10788.20 91.85 280.04 22 10821.56 89.07 279.17 23 10836.94 88.39 278.95 24 10864.19 88.15 279.46 25 10893.45 87.91 278.79 8-Jul-2000 15:09:03 Course TVD Vertical Displ Displ length depth section +N/S- +E/W- (ft) (ft) (ft) (ft) (ft) 0.00 90.50 33.50 21.00 16.48 26.83 29.70 29.59 24.82 24.57 26.43 35.68 27.34 31.02 32.81 19.57 42.92 62.98 38.06 26.20 33.20 33.36 15.38 27.25 29.26 26 10906.13 87.67 278.74 12.68 Projected To TD 27 10960.00 86.70 278.55 53.87 10107.00 10197.41 10230.60 10250.85 10266.27 10290.07 10313.37 10332.28 10344.47 10353.03 10359.64 10367.38 10372.91 10378.12 10381.57 10382.58 10381.91 10378.04 10375.00 10372.81 10371.09 10370.83 10371.17 10371.99 10373.00 10373.48 10376.13 [(c)2000 Anadrill IDEAL ID6_iA_21] 313.63 72.52 -307.02 317.35 74.49 -310.52 321.60 74.63 -314.79 327.00 74.27 -320.28 332.80 74.71 -326.06 345.10 76.68 -338.22 363.41 78.38 -356.46 385.98 78.'82 -379.14 407.43 79.11 -400.73 430.33 79.71 -423.73 455.83 80.80 -449.29 490.64 83.98 -483.97 517.41 87.07 -510.56 547.98 90.58 -540.93 580.60 94.69 -573.30 600.14 97.42 -592.65 643.02 104.14 -635.02 705.82 114.61 -697.00 743.73 120.78 -734.43 769.82 125.01 -760.20 Page 2 of 2 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) i00f) type type 315.47 283.29 319.33 '283.49 323.51 283.34 328.77 283.06 334.51 282.91 346.80 282.77 364.97 282.40 387.25 281.74 408.46 281.17 431.16 280.65 456.50 280.20 491.20 279.84 517.93 279.68 548.47 279.51 581.06 279.38 600.60 279.34 643.50 279.31 706.36 279.34 744.30 279.34 770.41 279.34 802.94 130.63 -792.87 803.56 279.36 836.26 136.19 -825.76 836.91 279.37 851.63 138.61 -840.94 852.29 279.36 878.85 142.97 -867.83 879.53 279.36 908.07 147.61 -896.70 908.77 279.35 920.74 149.54 -909.22 921.44 279.34 975.24 279.30 974.52 157.63 -962.42 0.00 TIP 2.34 GYR 26.02 GYR 35.48 GYR 35.09 SP 35.75 SP 6-axis 42.39 SP 6-axis 41.10 SP 6-axis 36.17 SP 6-axis 38.03 SP 6-axis 12.86 SP 6-axis 9.67 SP 6-axis 1.87 SP 6-axis 12.02 SP 6-axis 11.06 SP 6-axis 14.35 SP 6-axis 11.84 SP 6-axis 0.51 SP - 4.88 SP 6-axis 5.48 SP 6-axis 6.96 SP 6-axis 8.73 SP 6-axis 4.65 SP 6-axis 2.07 SP 6-axis 2.43 SP 6-axis 1.93 SP 6-axis 1.83 MWD - RF_C rc IV , U6 7::,0 Co,...'-~s. Alask-~u.."m 8,. p.,nchofa9e RE: SCU 23A-9 initial BOP test pressure - - PERMIT TO DRILL # 200 -073 Subject: RE: SCU 23A-9 initial BOP test pressure - - PERMIT TO DRILL # 200 -073 Date: Sun, 25 Jun 2000 07:29:54 -0700 From: "Hauck, Shane R" <haucks~unocal.com> To: "Wondz¢ll, Blair E-Vendor" <Blair_Wondzell~admin.state.ak.us> ..... Original Message ..... From: Wondzell, Blair E -Vendor Sent: Thursday, June 22, 2000 11:04 AM To: Billingsley, Tim -Contract Cc: Hauck, Shane R; Williamson, Dan R; Tom Maunder Subject: Re: SCU 23A-9 initial BOP test pressure 200-073 PERMIT TO DRILL Tim, I've looked at your request and reviewed the well file. We note the reservoir pressure is estimated at 2000 psi (at TD). We also note this is to be a horizontal sidetrack starting from the top of the Hemlock Zone. Therefore we agree with Bo Brown of the BLM'and conclude that an initial test pressure of 4200 psi is reasonable. You hereby have commission approval to change the initial BOP test pressure to 4200 psig. Sincerely, Blair Wondzell, 6/22/00. "Billingsley, Tim -Contract" wrote: > Mr. Wondzell, > The initial pressure test of the BOP equipment at SCU 23A-9 is in progress. > The approved AOGCC permit to drill requires a 5000 psi initial test and > subsequent tests to 3000 psi. > There have been some choke manifold leaks requiring some time and retesting. > We have been using a Dowell high pressure pump skid to attempt the 5000 psi > test. There is a smaller triplex pump at the Swanson River field that can > achieve 4200 psi test pressure. Due to the delays and the high costs of > Dowell on location, we have released them for now until the choke manifold > is repaired and a 4200 psi pre-test can be accomplished. > Bo Brown with BLM has been on location and has agreed to a 4200 psi test > instead of a 5000 psi test as far as BLM is concerned. > > Unocal is requesting from AOGCC a reduction on the 5000 psi intial BOP test > requirement to 4200 psi for SCU #23A-9. > Thanks for your consideration. > > Tim Bil lingsl ey > 263- 7659 1 of 2 6/26/00 7:42 AM Re: SCU 23A-9 initial BOP test pressure - - PERMIT TO DRILL # 200-073 Subject: Re: SCU 23A-9 initial BOP test pressure - - PERMIT TO DRILL # 200-073 Date: Thu, 22 Jun 2000 11:03:43 -0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Billingsley, Tim-Contract" <billita~unocal.com> CC: "Hauck, Shane R" <haucks~Orion. Unocal.com>, "Williamson, Dan R" <williamsond~Orion. Unocal.com>, Tom Maunder <torn_maunder~admin.state.ak.us> Tim, I've looked at your request and reviewed the well file. We note the reservoir pressure is estimated at 2000 psi (at TD). We also note this is to be a horizontal sidetrack starting from the top of the Hemlock Zone. Therefore we agree with Bo Brown of the BLM and conclude that an initial test pressure of 4200 psi is reasonable. You hereby have commission approval to change the initial BOP test pressure to 4200 psig. Sincerely, Blair Wondzell, 6/22/00. "Billingsley, Tim -Contract" wrote: Mr. Wondzell , The initial pressure test of the BOP equipment at SCU 23A-9 is in progress. The approved AOGCC permit to drill requires a 5000 psi initial test and subsequent tests to 3000 psi. There have been some choke manifold leaks requiring some time and retesting. we have been using a Dowell high pressure pump skid to attempt the 5000 psi test. There is a smaller triplex pump at the Swanson River field that can achieve 4200 psi test pressure. Due to the delays and the high costs of Dowell on location, we have released them for now until the choke manifold is repaired and a 4200 psi pre-test can be accomplished. Bo Brown with BLM has been on location and has agreed to a 4200 psi test instead of a 5000 psi test as far as BLM is concerned. Unocal is requesting from AOGCC a reduction on the 5000 psi intial BOP test requirement to 4200 psi for SCU #23A-9. Thanks for your consideration. Tim Billingsley 263 - 7659 1 of 1 6/22/00 11:04 AM ALASKA OIL AND GAS CONSERVATION COH~IlSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 9950 t -3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 123A. 1 Re~ The Application of UNOCAL for the Drilling of the SCU 23A-9 Well in the Swanson River Field Mr. Shannon W. Martin Legal Analyst UNOCAL P.O. Box 196247 Anchorage, AK 99519-7600 Dear Mro Martin: An application,, dated May 18, 2000, requested approval to drill the SCU 23A-9 well, which would be the third completion in the NW 'A Section 9, T7N, R9W, SM. It is understood by the Alaska Oil and Gas Conservation Commission (Commission) that the drilling and completion of the well should result in accelerated recovery of reserves from the Swanson River Field. The Commission hereby authorized drilling and com'>letion of the SCU 23A-9 well pursuant to Rule 5 of Conservation Order No. 123A. DONE in Anchorage, Alaska this day June _~_, 2000. Cammy Oechsli Taylor Commissioner Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION ALASKA OIL AND GAS CONSERVATION COPlPllSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Williamson Drilling Manager UNOCAL P O Box 196247 Anchorage, AK 99519-6247 Re~ Soldotna Creek Unit SCU #23A-9 UNOCAL Permit No: 200-073 Sur Loc: 2520'FSL, 1970'FWL, Sec. 9, T7N, R9W, SM Btmhole Loc. 2495'FNL, 946'FWL, Sec. 9, T7N, R9W, SM Dear Mr. Williamson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission at 279-1433. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~ff_- day of June, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill Redrill X I lb. Type of well Exploratory Stratigraphic Test Development Oil Re-entry DeepenI Service Development Gas Single Zone Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Unocal 1'35' RKB Swanson River Field 3. Address P.O. Box 196247 6. Property Designation Hemlock Anchorage. Ak 99519-6247 A-028997 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (see 20AAC25.025) 2520' FSL and 1970' FWL Sec. 9, T7N, R9W, SM Soldotna Creek Unit AK Statewide Oil & Gas Bond At t,o,p of productive int.e, rval Hemlock H~ @ 10388' TVD 8. Well Number Number 2630 FSL and 1525 FWL Sec. ~/~,..-i'7N, R9W, SM SCU #23A-9 U 62-9269 At total depth ~)[]) 9. Approximate spud date Amount 2495' FNL and 946' FWL Sec. 9, T7N, R9W, SM 6/10/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15 Proposed depth (MD and TVD) property line 671' (SCU #312-9) 11054' MD 3590' @ TD Lease 2560 acres 10415' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2) Kickoff depth 10177 feet Maximum hole angle 90° Maximum Surface 1005 psig. At total depth (TVD) 2000 psig 18. Casing Setting Depth program size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD 6" 3-1/2" 9.2 L-80 Flush Jt 977' 10077' 10777' 11054' 10415' None, slotted liner 19. To be completed for Redrill, Re-entry and Deepen Operations ~ ~'~'~, ~ ~ Present well condition summary ~ 't.~,f~ ...... ~.,..~ ....... ~ V Total depth: measured 13821 feet Plugs (measured) true vertica~ 13821 feet MAY '1 5 2000, Effective Depth measured 10652 feet Junk (measured) ~,.~ . true vertical 10652 feet A?,ch0r~e Casing Length Size Cemented Measured Depth True Vertical Depth Structural Conductor 32' 20" Drive 32' 32' Surface 2009' 11-3/4" 1800 sx 2009' 2009' Intermediate Production 10748' 7" 1500 sx 10748' 10748' Liner Perforation Depth: measured 10150'-10620'0RI INAL true vertical 10150'-10620' 21. I he, r, eby certify that ~e~regoing is true and correct to the best of my knowledge Signe(~_,~'~~~/'~ -- Title: Drilling Manager Date Commission Use Only Permit Number I APl Number I Approval date ,,~;,1,~ I See cover letter ~--.-~)~ '""~)'7.~ 50- /.~ ._,~-'"/~)/Z.~-(.~ I ~,..-- ~ forother requirements Conditions of approval Samples required Yes ~ Mud Icg required_ Yes ~ '-O ,% ~..~C~,-~:~,.\ %~' ~-~:~" Hydrogen Sulfide measures Yes /'lq~'~ DirectionaLSurvey required /~?-e-~') No ,'> Required working pressure for BOPE 2"-~ 3M ~ 10M 15M ~ %~C3(5 c,~,, .~;x,¢:~,,~,-~ Other'. ~ )RIGiN' .... AL $I(5t'~ ¢ '~ .... ' ,':';' '~ by order of Approvedby "r~ T~,,Ic, r~,s,*m~O,,,,, Commissioner the commission Date ~¢'/~ Form 10-401 Rev. 12-1-85 AFE# Submit in triplicate Unocal Alaska Resources Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCALe May 1B, 2000 Commissioner Robert N. Christenson Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 S°ldotna Creek Unit #23A-9 ADMINISTRATIVE APPLICATION FOR VARIANCE: RULE 5, CONSERVATION ORDER 123-A Dear Chairman Christenson: Enclosed and submitted in triplicate is our application for Permit to Drill Soldotna Creek Unit A-28997 Well 23A-9 (form 10-401) pursuant to 20 AAC 25.005 and our check No. 2003591 in the amount of $100.00 as required under 20 AAC 25.005 (c) (1). Verification of Application by the undersigned stating that applicant is acquainted with the facts, pursuant to 20 AAC 25.055 (d)(3), is attached as part of this application. It is requested that the Commission approve an administrative variance to Rule 5, Conservation Order 123-A for the drilling of well SRU #23A-9, A-28997, as the addition of #23A-9 will cause more than two completed wells to be within the northwest governmental quarter-section of Section 9, T7N, R9W, SM. Soldotna Creek Unit Well 23A-9: The specific location, interval, and depth are as follows: Surface Location: 2520' FSL and 1970' FWL Sec. 9, T7N, R9W, SM Top of Productive interval: 2630' FSL and 1525' FWL Sec. 9, T7N, R9W, SM Total Depth and Location: 2495' FNL and 946' FWL Sec. 9, T7N, R9W, SM The lease is currently beyond its primary term and is being held by the Soldotna Creek Unit. RECEIVED · . . , ay 2:5 2000 AlaSka 0i1 & Gas Cons. Commission All applicable provisions of 20 AAC 25.050 (Deviation) have been met for each owner and all operators of governmental sections directly or diagonally offsetting the section' where the gas wells are located. Unocal is the owner and operator of all directly or diagonally offsetting sections; therefore, notices by registered mail pursuant to 20 AAC 25.055 (d) are not necessary. If you require additional information, please contact Shannon Martin at 907-263-7882, or Tim BillingsleY, Drilling Department at 907-263-7659. Sincerely, Enclosures ., ¥ 2 ;5 2_000 Oil & Gas (~s. Commission ~chorage VERIFICATION OF APPLICATION FOR SPACING EXCEPTION COOK INLET, ALASKA Lease # 28997 Well: Soldotna Creek Unit #23A-9 I, SHANNON W. MARTIN, Legal Analyst, Union Oil Company of Califomia, do hereby verify the following: I am acquainted with the application submitted for the drilling of the Soldotna Creek Unit #23A-9 Well. I have reviewed the application submitted for the exception to 20 AAC 25.055 (a)(4) (statewide spacing) and all facts therein are true. I have reviewed the plat attached to said application, and it correctly portrays pertinent and required data. DATED at Anchorage, Alaska this 15th day of 2000. ~--~h~nn~n g¢¢. Martin Legal Analyst STATE OF ALASKA THIRD JUDICIAL DISTRICT ) ) ss ) SUBSCRIBED TO AND SWORN before me this 15th day of May 2000. NOTARY PUBLIC II~ THE STATE OF ALASKA My Commission expires: MAY 1 5 2000' · Unocal Alaska Resources Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL ) May 15, 2000 Commissioner Robert N. Christenson Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Soldotna Creek Unit #23A-9 REQUEST FOR SPACING EXCEPTION A- 28997 Dear Chairman Christenson: Enclosed and submitted in triplicate is our application for Permit to Drill Soldotna Creek Unit A-28997 Well 23A-9 (form 10-401) pursuant to 20 AAC 25.005 and our check No. 2003591 in the amount of $100.00 as required under 20 AAC 25.005 (c) (1). Verification of Application by the undersigned stating that applicant is acquainted with the facts, pursuant to 20 AAC 25.055 (d)(3), is attached as part of this application. It is requested that the Commission approve an exception to the statewide spacing regulation 20 AAC 25°055 (a)(4) for the drilling of well SRU #23A-9, A-28997. Soldotna Creek Unit Well 23A-9: The specific location, interval, and depth are as follows: Surface Location: Top of Productive interval: Total Depth and Location: 2520' FSL and 1970' FWL Sec. 9, T7N, R9W, SM 2630' FSL and 1525' FWL Sec./~, TTN, R9W, SM 2495' FNL and 946' FWL Sec. 9, T7N, R9W, SM The lease is currently beyond its primary term and is being held by the Soldotna Creek Unit. All applicable provisions of 20 AAC 25.050 (Deviation) have been met for each owner and all operators of governmental sections directly or diagonally offsetting the section where the gas wells are located. Unocal is the owner and operator of all directly or diagonally offsetting sections; therefore, notices by registered mail pursuant to 20 AAC 25.055 (d) are not necessary. If you require additional information, please contact Shannon Martin at' 907-263-7882, or Tim Billingsley, Drilling Department at 907-263-7659. Sincerely, Enclosures A-28396 UOC I i ! , u°c'---~l i ::' ! "'~ , A-28997 i , .. ~ . ..~: UOC · 1,--'1 [ . ' . ~1,-,.4 __ A-28996 a~ A-28997 - uoc ! uoc. '-~ 9 8 , ! ~ ' i SOLDOTNA CREEK L I ~ ~___ 17 g ...... I ~ ;L '~ , SCALE IN FEET I 1 411-! I ! ! i ! _[ i A-28997 ~ UOC l i I I I i --I ! ~997 OC t0 I i i. I I u#ocJu. O Soidotna Creek Unit ~r'o~l #.- z~- ~ PROPERTY PLAT £~u~) T.S. -33 I / L~rD~G / / / / I I I I . / ~1/ II SP 46'N 2a70000 60' 45'y LOCKED CATE 2~5~0 AND SHOP 332--0 \\ 'P.P_.~SOR ! I I / / / / / .../ / / ./ UNOCALO KENN PENINSULA SWANSON RIVER FIELD ~11 qOlll 60' 44"N 2,L~oooo 2 ~.~,~0 60' 43'~V 2450000 60' 42'.~ Hazard Section Application for Permit to Drill SCU #23A-9 There are no known over-pressured intervals in the proposed drilling of SCU #23A-9. The deep kick-off point of 10,177' MD/TVD is between the G-1 and G-2 intervals. The rest of the drilling to TD of 11,054'MD/10,415'TVD will be in the Hemlock. Data from the Hemlock and G-2 zone indicates a depleted pore pressure of 0.20 psi/ft for an equivalent mud weight of 3.8 ppg. The proposed oil based mud program of 8.4 ppg mud density will be sufficient to control the reservoir pressure down to 11,054' TD. Lost circulation is possible while drilling the well so attention will be directed towards good drilling practices including slow trips in/out of the hole, accurate monitoring of trips with a trip sheet and keeping the hole full by circulating over the top of it. Lost circulation will be treated initially with Ventrol 401. If losses still occur, 100 ppb liquid casing and CaCO3 will be added to the oil based mud sysstem. Mud and Cuttings Disposal The oil based mud from SCU #23A-9 will be disposed in the mud disposal well, SCU #43-4MD. The cuttings generated by drilling #23A-9 will be disposed in the solid waste facility at Swanson River Field. Abandon SCU #323-9 1) 2) 3) 4) 5) 6) General Sidetrack Procedure SCU #23A-9 (Formerly SCU #323-9) RU E-line and set cement retainer in 2-7/8" tubing at 10,425'. RU coil tubing, RIH and sting into cement retainer at 10,425'. Mix and pump cement to abandon Hemlock HB-8, HB-9 and HB-10 perforations. Appx cmt volume= (10652'-10441') x .0371 bbl ft for 7" 29#= 7.8 bbl (10441'-10259') x .00579 bbl ft for 2-7/8" tbg = 1.1 bbl Total cmt volume = 8.9 bbl. Displace cement with water, leaving appx 1 bbl of cement above retainer at 10,425'. Unsting from retainer and PU to 10259', circ out any excess cement. POOH and rig down coil tubing unit. Redrill SCU #23A-9 1) 2) 3) Move in Inlet Drilling Rig #CC-1. ~/IAY 1 $ 2000 NU and Test BOPE. Ala~ka Oil & G~ (?<m:~. Con'~mis.~,ioi'~ Pull completion tubing and retrievable packer at 9987'. gnc,~o~,~ 4). 5) Run casing scraper below 10,177'. RU e-line and set 7" bridge plug at approximately 10,177'. 6) RIH with 7" whipstock on drill pipe. Orient and set whipstock on top of bridge plug at 10,177', 7) Mill window at 10,177' and commence horizontal redrill of SCU #23A-9. 8) Directionally drill 6" hole from 10,177' MD/TVD to 11,054' MD/10,415' TVD. 9) Run 3-1/2" Hydril 511 slotted liner with 2-1/16" inner string from TD to 10,077'. 11) 12) 13) 14) 15) Set hanger, release from hanger and flush out mud outside and inside slotted liner via 2-1/16" inner string. POOH with inner string. RIH with liner top packer on drill pipe. Set 3-1/2" x 7" liner top packer, pressure test liner top packer to 2500 psi. POOH with drill pipe and packer setting tool. Run 3-1/2" tubing completion with seal assembly stabbed into liner top packer tie-back sleeve. Completion includes methanol injection mandrel with chemical injection line down to appx 2500' and appx five gas lift mandrels for kick- off/unloading purposes. Install and test tree. Move drilling rig. Install flowline and methanol injection pump at surface. Gas lift well if necessary to initiate gas production. UNOCAL Proposed Well Profile - Geodetic Report Client: Unocal' ' Field: Swanson River Unit Structure: Soldotna Creek Unit 323-09 Well: 323-09 Borehole: 323-09A UWI/AP~: 501331012601 Date: May 04, 2000 Grid Convergence: -0.75818982° Scale Factor. 0.99992759 Location: : Coordinate System: N 60 42 43.783, W 150 52 9.462 N 2453261.000 ItUS, E 344303.000 flUS NAD27 Alaska State Planes. Zone 04. US Feet ii i Survey Computation Method: Minimum Curvature' DL$ Computation Method: Lubinski Vertical Section Azimuth: 284.110° Vertical Section Origin: N 0.000 fl. E 0.000 ft TVD Reference: KB 135.0 fl above MSL · Magnetic Declination; 21.480° Total Field Strength: 55290.487 nT Dip: 73.546° Declination Date: April 27. 2000 Magnetic Declination Model: BGGM 1999 North Reference: True North Coordinate Reference To: Well Head Schlumberger (~rid Coordinates Geographic Coordinmsl I .StafionlD J MD I incl I Azim I TVD i VSa=' ! N/'$ I E/'W '1 DLS(ff,. (°, . . (°) (fi) (fi, (fi, (fi, (°llOOft, N°rthlng I Easting(flUS, (ftUS) Latitude Longitude Tie-in Survey 10115.00 1.50 304.09 10107.00 315.44 72.52 -307.02 0.00 2453337.57 343996.99 N 60 42 44.497 W 150 52 15.633 Top Whipstock Base Whipstock Build 22.4/100 Base G1 Top G2 Top H1 Top H2~.:. ~-' Top H~i Top H5 End Build 10165.00 1.54 303.86 10156.99 316.69 73.26 -308.12 0.08 2453338.33 343995.90 N 60 42 44.504 W 150 52 15.655 , 10177.00 3.40 285.00 10168.98 317.19 73.44 -308.60 16.67 2453338.51 343995.42 N 60 42 44.506 W 150 52 15.664 10182.00 3.40 285.00 10173.97 317.49 73.52 -308.89 0.00 2453338.60 343995.13 N 60 42 44.507 W 150 52 15.670 10183.03 3.63 285.00 10175.00 317.55 73.54 -308.95 22.36 2453338.62 343995.07 N 60 42 44.507 W 150 52 15.671 10200.00 7.42 285.00 10191.88 319.19 73.96 -310.53 22.36 2453339.06 343993~50 N 60 42 44.511 W 150 52 15.703 ~'~..~0235.86 15.44 285.00 10227.00 326.29 75.80 -317.38 22.36 2453340.99 343986.67 N 60 42 44.529 W 150 52 15.841 ~-~?0294.21 28.49 285.00 10281.00 348.06 81.43 -338.42 22.36 2453346.90 343965.71 N 60 42 44.585 W 150 52 16.264 ~-~0300.00 29.78 285.00 10286.06 350.88 82.16 -341.14 22.36 2453347.66 343963.00 N 60 42 44.592 W 150 52 16.318 ~'~ "~10338.61 38.42 285.00 10318.00 372.51 87.76 -362.03 22.36 2453353.54 343942.19 N 60 42 44.647 W 150 52 16.738 ~.~10385,6 48.95 285,00 10352,00 404,97 96,17 -393,40 22,36 2453362,36 343910,94 N 60 42 44,730 W 150 52 17,369 i~i~?10400.00 52.15 285.00 10361.09 416.02 99.02 -404.07 22.36 2453365.35 343900.31 N 60'42 44.758 W 150 52 17.583 :ii ~'-~0450.59 63.46 285.00 10388.00 458.75 110.09 -445.35 22.36 2453376.97 343859.18 N 60 42 44.867 W 150 52 18.413 ;~.~?10500,00 74.51 285.00 10405,69 504,80 122,01 -489.84 *22,36 2453389,47 343814,85 N 60 42 44,984 W 150 52 19,307 10569,27 90,00 285.00 10415.00' 573.22 139,72 -555,93 22,36 2453408.05 343749,01 N 60 42 45,159 W 150 52 20,635 TD 11054.27 90.00 285.00 10415.00 1058.16 265.24 -1024.41 0.00 2453539.75 343282.27 N 60 42 46.395 W 150 52 30.051 323-09A (P2). Report Page I of I 5/4/00-5:08 PM 'UNOCAL ) Client: Unocal Well: 323-09 Field: Swanson RiVer Unit. Structure: Soldotna Creek Unit 323-09 Scale: 1 in = 200 ft Date: 04-May-2000 Schlumberger A A A V V V -1200 · -1000 --800 -600 -400 -200 0 200 : :' 11054 MD 10415 T/D 90.00° 285.00' az i~°P Whipstock 265 N 1024 W / 0165 MD 10157 TVD End Build/ .54' 303.86° az .. ~ / 10569MD '10415TVD '~3N 308W / Tie-in Survey 10115MD 10107'[ /D · 1.50° 304.09' az Hold.mOth ?85.00. 73 N 307 W r Build ~...4/100 10182 MD 10174 TVD Base Whipstock 323-09 3.40° 285.00° az 10177 MD 10169 '1¥[ 74 N 309 W 3.40° 285.00° az !73N 309W -1200 -1000 -800 -600 -400 -200 0 200 <<< WEST EAST >>> 300 UNOCAL ) ~TICALSECTIONVIEW Client: Unocal Well: 323-09 Field: Swanson River Unit Structure: Soldotna Creek Unit 323-09 Section At: 284.11 deg Date: May 04, 2000 lo4oo 10200 - Schlumberger 'ri.,-in Survey 1( 115MD 1010?IVD 1. ;0, 304.09' az 3' 5 departure / Top Whipstock / 10165MD 10157' VD - '~ 1.54° 303.86° az 317 departure _~- Base Whipste ck i _./ 10177MD 10169TVD BaseG1 10183MD 1017STUD ~ -- - 37.40' 2B~DU'~ _ _ ~..~7 departure Build 22.,I/100 TopG2 10236 MD 10227 FVD · ' ' -10-{8~-M£ '~'0174'TVD 3'40° 285'00° az317 depa ture ........ , 'l'~pH1 10294MD 1021 1TVD / End Build ITop H2 10339 MD 1C )18 TVD' 10569 MD 10415'i~ :) 90.00' 285.00°az ....... - 5~3 ~ufe-- T~3 H_.3 1.._03_86_ME _1_O352 _T~ .... ; _ _ Top_H5 1~_)451 M.__D 10_388_TV_D _ _ _ -Iold Angle 90.00' 11o54 MD 10415 T 90.00° 285.00" az 1058 ¢ eparture .~ _ I 200 1050~ 300 400 500 600 700 800 900 1000 Vertical Section Departure at 284.11 deg from (0.0, 0.0). (1 in = 100 feet) Swanson River Well SCU #23A-9 Bottomhole Pressure Information The following presents data used for calculation of anticipated surface pressures (ASP) during drilling of the sidetrack SCU 23A-9. The pore pressure gradient was estimated from the following information: BHP Depth Well psi TVD.. EMW, pp.a Comment 323-9 2000 10051 3.8 ppg or .20 psi/ft Depleted Hemlock and G-zone The fracture gradient at sidetrack window at 10,177' is estimated at .70 psi/ft or 13.5 PPg. Casing Pore Casing Setting Fracture Pressure Mud Pore ASP Size Depth Gradient Gradient Weight Pressure Drilling (in.) (TVD ft) (Ibs/clal) (Ibs/~al) (Ib/~al) (psi) (psi) 7" 10177 13.5 3.8 8.4 2000 1005 3-1/2" Inr 10415 NA 3.8 8.4 2047 Procedure for Calculatinq Anticipated Surface Pressure While Drillinq ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat (with gas bubble just below shoe and mud gradient above shoe) or 2) formation pore pressure at the next. casing point less gas gradient to the surface as follows: 1) ASP = (FGx.052xD) - (MWx.052xD) = (13.5 x .052 x 10177) - (8.4 x .052 x 10177) =2699 psi OR 2) ASP = FPP - (0.1gas gradient xD) = 2047 - (. lxl 0415) = 2047 - 1042 = 1005 psi SCU #23A-9 Casing Design 7" Production Casinq, 29 #, 26# and 23# N-80 Worst case for burst is tubing leak near the surface after the well is completed. Burst=l 0,415' x((3.78 formation x .052) - 0.1 gas grad)) - 1005 psi 7" 23# rated @ 6340 psi for burst Safety Factor = 6.3 OK Worst case for Collapse is if lost returns occur while drilling below the 7" casing. Collapse - (8.33 x.052x10177') -(10177' x .1 ) - 3390 psi for full evacuation 29# rated @ 7020 psi for clpse Safety Factor = 2.1 OK Collapse = (8.33 x .052 x 6543')-(6543' x .1 ) = 2180 psi for full evacuation . 26# N-80 Rated @ 5410 psi Safety Factor = 2.5 OK Collapse = (8.33 x .052 x 471'5')-(4715' x .1) = 1571 psi for full evacuation 23# N-80 Rated @ 3830 psi Safety Factor = 2.4 OK Tension = NA (casing already in place and cemented) 3-1/2" 9.2#, L-80, slotted liner @ 11054' MD/10415' TVD Tension = (11054'-10077') x 9.2#= 9K Rated = 207K for body yield Safety Factor = 23 OK Collapse = Not applicable for slotted liner Burst = Not applicable for slotted liner SCU #23A-9 Casing Specifications Proposed Casing Liner 3-1/2, 9.2#, L-80,Flush Joint. Tubing, slotted Joint Strength, K lbs 207 Body Strength, K lbs 207 ., Burst Rating, psi NA, slotted liner Collapse Rating, psi NA, slotted Cplg OD, in (flush jt) 3.5 CSGSPEC 23A-9.xls SCU 23A-9 Cementing Program 3-1/2" Slotted Liner The deep kick-off point of 10,177' results in the proposed sidetrack penetrating only the G-2 and Hemlock intervals. It is not necessary to isolate the G-2 from the HemloCk productive intervals so a slotted liner will be run instead of cementing a solid liner. The cement bond log on 7/12/61 indicates good .isolation behind the 7" casing between all zones up to 9700'. RECEIVED UNOCAL ) MAY 2 2 2000 Alaska 0~; & Gas Co~s. Commiasio~ ........ II i ii ii -'' ir I I IIii ...... RKB to TBG Hanger = 14.65' Tree connection = 2-7/8' 8rd TBG Cut 10,366' 16 18 19 - t~, 20 PBTD = 10,652' Ti) = 13,821' MAX HOLE ANGLE = Straight 323-9 schematic.doc ?? , , /,.,d ;68; ON Swanson River Field Well # S CU 323-9 Actual Completion 9/11/96 DV @ 6,796' 3 4 5 Pulled 9/6/99 9 10 ~ %~"x\ 11 12 13 ' 14 ~ 15 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 20" Surf 32 11-3/4" 47 8rd Surf 2,009 7 29 N-80 Buttress Surf 288 7 26 N-80 Buttress 288 1,048 7 23 N-80 Buttress 1,048 4,715 7 26 N-80 Buttress 4,715 6,543 7 29 N-80 Buttress 6,543 8,369 ' 7 29 N-80/P-110 L8R 8,369 i0,748 Tubing: 2-7/8" 6.5 L-80' Buttress Surf 10,065 2-7/8" 6.5 L-80 . Buttress 10,259 10,365 2-7/8" 6.5 N-80 EUE 8rd ABC 10,366 10,623 NO, Top Depth. i 14.65 2 3 9,987 4 10,033 5 10,065 6 10,259 7 10,263 8a 10,310 8b 10,351 8c 10,359 9 10,364 x/ 10 10,371 11 10,379 12 10,419 13 10,436 ./ 14 t0,441 15 10,448 16 10,557 17 10,576 /' 18 10,583 19 10,589 20 · 10,624 TOP BTM JEWELRY DETAIL Item Tubing hanger with Cames-on BPV profile Camco MMM Gas.Lift Madnrels with 10' pups @ 1,640', 2,669', 3,662', 4,657', 5,429', 6,046', 6693°, 7,373', 8,017', 8670', 9,318', 9.934' with live gas lift valves Baker FH (50K) Reu'ievable Packer ' Baker X-Nipple profile (ID ~ 2.313") Baker Wiroline R~-entry guide Baker SC-2P Retrievable Packer Bakex retrieving extension Baker CMU sliding sleeve (ID = 2.313") Baker X-nipple (ID -- 2.313") Baker Telescoping Joint ' Bowen Series 150 Overshot Guide w/grapple Baker FH Packer Otis $ nipple Position ~2 ID -- 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH packer, Otis S nipplePosifion #1 ID-- 2.313" Camco MM Gas Lift Mandrel Brown. CC Safety Joint Baker Fl{ Packer Camco D Nipple ID = 2.25" Bakex Shear-out Sub PERFORATION DATA ZONE SPF DATE COMMENTS 10,150 10~168 G-1 6 2/7/98 Existing 10,226 10,246 G-2 4 9/17196 Existing 10,280 10,300 H. 1- ~'\cx- Existing ,10,317 10,343 H-2 Existing - Existing. 10,351 10,364 H-3 ~ ~ ?\,.x~ 10.388 10,434 1-I-5_..V,..k. ~' Existing 10,455 I0,545 H-8 Existing -- Existing 10,554 10,580 H-9 ~% ~,kc 10,592 10,620 H-10 Existing W.S.O @ 10.276' and 10,625' REVISED: 05/14100 'daO3 lVOONn 000~ UNOCAL ) RKB to TBG Hanger = 14.65' Tree connection = 2-7/8" 8rd DV @.6,796' SIZE WT 20" 11-3/4" 47 7 29 7 26 7~ 23 7 26 7 29 7 29 Tubing: Swanson River Field Well # SCU 23A-9 (Formerly 323-9) Proposed Sidetrack, 6/2000 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM Surf 32 8rd Surf 2,009 N-80 Buttress Surf 288 N-80 Buttress 288 1,048 N-80 Buttress 1,048 4,715 N-80 Buttress 4,715 6,543 N-80 Buttress 6,543 8,369 N-80/P-110 L8R 8,369 10,748 TBG Cut @ 10,366' Proposed. Cmt @ 10,425' 8a 8b 9 10 11 12 13 14 15 Hemloc~ 16 HB-8, lin_9? 17 18 HB-10 N,& 19 20 PBTD = 10,652' TD = 13,821' MAX HOLE ANGLE = Straight SCU 23A-9 proposed sidetrack.doc NO. Top Depth 4 10177' 5 10177' 6 10.259 7 10.263 8a 10.310 8b 10.351 8c 10..359 9 10.364 10 10..371 11 10,379 12 10,419 13 10,436 14 10,441 15 10,448 16 10,557 17 10,576 18 10,583 19 10,589 20 10,624 JEWELRY DETAIL Item 7" 29# whipstock 7" bridge plug Baker SC-2P Retrievable Packer Baker retrieving extension Baker CMU sliding sleeve (ID = 2.313") Baker X-nipple (ID = 2.313") Baker Telescoping Joint Bowen Series 150 Overshot Guide w/grapple Baker FH Packer Otis S nipple Position #2 ID = 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH Packer, Otis S nipple Position #1 ID = 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH Packer Camco D Nipple ID = 2.25" Baker Shear-out Sub PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 10,'151} 10,168 G-1 6 2/7/98 Existing 10,226 10,246 G-2 4 9/17/96 Existing 10,280 10,300 H-1 Existing 10,317 10,343 H-2 Existing 10,351 10,364 H-3 Existing 10,388 10,434 H-5 Existing 10,455 10,545 H-8 Existing 10,554 10,580 H-9 Existing 10,592 10,620 H-10 Existing W.S.O @ 10,276' and 10,625' REVISED: 05/14/00 DRAWN BY: TAB UNOCAL RKB: 14.65' SIZE 20" 11-3/4" 7" 7" 7" 7" 7" 3-1/2" liner slotted Tubing 3-1/2" 47 29 26 23 26 29 9.3 9.3 WT ~wanson River Well SCU 23A-9 Proposed Sidetrack Completion CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. N-80 N-80 N-80 N-80 N-80/P110 L-80 L-80 32' 8rd 11.000 Surface 2009' Buttress 6.184 Surface 288' Buttress 6.276 288' 1048' Buttress 6.366 1048' 4715' Buttress 6.276 4705' 6543' Buttress &8rd 6.184 6543' 10177' Window Hydril 511 2.992 10077' 11054' Buttress 2.992 Surf 10077' NO. Depth 1 15' ID JEWELRY DETAIL OD Item 2 2.992 3.500 3 2000' 2.867 5.313 2.867 2.813 4 2,500' 5 10040' 6 10077' 7 10077' 8 10177' 9 10177' 10 11054' 5.500 Tubing Hanger, 7-1/16" x 3-1/2" Butt., Type" H" BPV profile. CL prep. 3-1/2" L-80 9.3 ft/lb Butt. tubing Gas Lift Mandrels Macco SFO-1, appx five total Methanol Injection Mandrel Macco SFO-1CI Baker 3-1/2" 'CMU' Sliding Sleeve Baker Locator type seal assembly (5.25" OD) Baker "ZXP" Liner Hanger with 10' tieback extension Baker Bottom Trip .Whipstock 7" bridge plug 3-1/2" liner shoe Kick offPoint @ 1.0177' ~ H5 TD = 11,054' MD/10,415' TVD MAX HOLE ANGLE = 90 deg SCU 23A-9 Proposed Schematic.doc Drawn by: TAB 05/11/00 7-1/16", 5M, Shaffer Annular 7-1/16", 5M, Shaffer Double Gate 7-1/16", 5M, Mud Cross w/3", 5 K, Outlets 7-1/16", 5M, Shaffer Single Gate 7-1/16", 5M, Spacer Spool 24" 17" 8" 12,' Concrete 9 I 30-1/2" 27" 15" 15-1/2" Aor>rox. 15" 7-1/16" 5M X 12" 3M Shaffer Tbg. Spool Mod. 55L1 Threaded I 1-3/4"x 12" 3M KD Head 20" 11-3/4" 12" Concrete 799 UNOCAL(~[ BOP Hookup Well SCU 323-9 Swanson River, Alaska Drawn by: TCB Date: 5-04-00 Blowout Prevention Equipment Inlet Drilling Rig #CC-1 or Equivalent 7-1/16" BOP Equipment 1 ea 7-1/16" x 5000 psi wp single ram type preventer 1 ea 7-1/16" x 5000 psi wp double ram type preventer 1 ea 7-1/16"x 5000 psi wp annular preventer Iea 7-1/16" x 5000 psi wp drilling spool with 2 ea 4" side outlets (choke and kill), HCR and manual valves on choke line and two manual valves on kill line. Kill line also has a check valve. Iea Koomey BOP control unit with 120 gallon volume tank, w/twelve 10-gallon accumulator bottles and nitrogen back-upsystem. Valve at annular preventer on Koomey line. 1 ea 5 station, remote control panel 1 ea 5,000 psi choke manifold with Cameron automatic hydraulic choke 3" - 10,000 psi with control choke panel. 1 lot Hydraulic pipe and fittings from manifold to BOP stack. Drilling Fluid Program Unocal Swanson River Unit SCU 323-9 May 12, 2000 Mud Type: Oil base invert oil mud (Versadrill) 6" hole Vendor: M I Formulation: Mapco 200 (200 degree flash point) Calcium chloride brine (10.2 PPG) V G-69 - organophlic clay Versacoat Versawet Lime Barite Calcium carbonate Properties: Mud Weight = 8.4 lb/gal Funnel Viscosity = 80 sec/qt 'Plastic Viscosity = 15 to 20 cps Yield Point = 12 to 20 lb/100 ft2 Gels = 12/20 lb/100 ft2 Oil Water ratio = 85/15 HPHT < 10 cc This well will be drilled using high flash pOint base oil - invert emulsion mud system. This system is recommended because of improved bore hole stability, reduced torque and drag and reduced chances of differential Sticking. Displacement to oil base mud will take place after milling the window. Properties will be adjusted as indicated from well conditions. Ali cuttings will be collected in cutting boxes and properly disposed. No fluids will be discharged. All fluids will be stored in contained 'areas. Lost circulation material will be available on location. After the well is drilled and the slotted liner is run. The slotted liner will be displaced to diesel. The oil mud system will be stored for use on a future project. Drilling Fluid System Description Inlet Drilling Rig #CC-1 Mud Pumps 1 ea PZ9 Gardner Denver, 3"x 5000 psi shear release valve and a 4" x 4000 psi gates bumper hose powered by a 398 TA Cat. 1 ea 214P Oilwell powered by twin 671 Detroit diesel engines. Mud Tank System (466 bbl Total Volume) Tank A- 88 bbl suction tank Tank B- 150 bbl middle tank Tank C- 172 bbl shaker tank Tank D- 27 bbl pill tank Tank E- 17 bbl centrifuge tank Tank F, 12 bbl sand trap Trip Tank- 35 bbl 501 bbl total Mud System Equipment Iea Iea Iea 1 ea Iea 3 ea 1 ea 1-ea 1 ea Brandt dual tandem 800 gpm shale shakers Driico See-FIo degasser 36"x 6' Poor Boy gas buster Pioneer eight cone desilter Pioneer Model S-800 mud hopper Medearis 3" revolving mud agitator guns Pit level indicator with audio and visual alarms Fluid flow sensor Gas monitoring for H2S and LEL with sensors at rig floor, sub and shakers. MUD TANKS ATTACHMENT E 13bls Bbl-- l-/'f Bbls/;.~h Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL Dan Williamson Drilling Manager May 15, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Re: Commissioner Robert N. Christenson Application for Permit to Drill (Form 10-401) Swanson River Field Soldotna Creek Unit #23A-9 (Formerly SCU #323-9) Commissioner Christenson: Enclosed is the Application to Drill (Form 3160-3) Soldotna Creek Unit Well #23A-9. This proposed well will be a Hemlock sand gas producer sidetracked from an existing vertical wellbore, SCU #323-9. The proposed sidetrack has a total course length of 877' of which approximately 500' will be "horizontal" through Hemlock Bench 5. A 3-1/2" slotted liner will be run in the 6" hole to provide hole stability in the production mode. The proposed sidetrack point in the 7" casing will be at 10,177' approximately between the depleted G-1 and G-2 zones so overpressure problems while drilling will not be a problem. The new well will be drilled to a TD of 11,054' MD/10,415' TVD. An MWD/GR will provide directional and lithological control for the wellpath. There is no history of hydrogen sulfide in the Swanson River Field in any of the formations that this proposed sidetrack will encounter. The expected start date for this well is June 10, 2000 so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263- 7677 or Tim Billingsley at 263-7659. i~cerel , Dan Williamson Drilling Manager MAY 1,5 2000 AnJ,or~e AOGCC cover letter 23A-9 redrill.doc Tim Billingsley .,, .~ ','L!-~E 5tJbr,flT1-Eb~ VENDOR NO. . DATE : ~ NO. ii~ ]_03'1548 '15-Ma¥-0( 200359'1 DATE INVOIC~CREDIT MEMO NO. ~HER NO. GRO~ DISCOUNT ~ ~ [5-~Y-O0 DR~PS~SCO2~A9 050030003~L5 ~00.00 ~00 FORM 4-2B181 (REV. 11-95)PRINTED IN U.S.A. [~~ . , . , , ; ~, ~ , , : ~/[ '~'~'~, :;:,~;:.:~ ~OO . OO ~ OO CITIBANK DELAWARE 62-20 A Subsidiary of Citicorp '311 ONE PENN'S WAY NEW CASTLE, DE 19720 Union Oil COmpany of California Accounts Payable Field Disbursing UNOCALG Pay One Hundred Dollars And 00 cents:*************************** To the order of STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DR ANCHORAGE, AK 99501 I ' ~'' 'ii~, '!'i?;~ I' Date V 15-MAY-00 Void after six months from above date'. 2003591 Check Amount i:i:ii STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: X Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: x Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: x 135 feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Soldotna Creek Unit Anchorage, AK 99519-6247 Service: 4. Location of well at surface 8. Well number 2520' FSL & 1970' FWL of Sec. 9, T7N, R9W, SBM SCU 323-9 At top of productive interval 9. Permit number Same 21-61 At effective depth 10. APl number Same 50- 133-10126-00 At total depth 11. Field/Pool Same Swanson River/Tyonek 12. Present well condition summary Total depth: measured 13821 feet Plugs (measured) true vertical 13821 feet Effective depth: measured 10652 feet Junk (measured) true vertical 10652 ,.,ORIGINAL Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 32' 20' 32' 32' Surface 2009' 11-3/4' 1800 sx 2009' 2009' Intermediate Production 10748' 7' 1500 sx 10748' 10748' Liner Perforation depth: measured See schematic ...... .,~. -. , true vertical Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-S0 at 10065' "i~:f' "~ '.-~ ~ ~-~Jv~;,'")C'"~f':' Packers and SSSV (type and measured depth) Baker Model FH @ 9987' , .. '. : ....... 13. Attachments Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 6/10/00 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereb/y~ertify tb,~t/4~¢f,Oregoing is true and correct to the best of my knowledge. Signe~~i~) ~ Williamscn Title: Drilling Manager 5'"'/,~' -'-- ,~- Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Apprq.v, al N9. / Plug integrity~ BOP Test Location clearanceI -- Mechanical Integrity Test Subsequent form required lO- Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST COMPANY WELL NAME PROGRAM: exp devv/ redrll t,/'" servwellbore seg ann. disposal para req FIELD & POOL 7"~__ _ /('~ INIT CLASS 'ZZ~"V - ~ ,:~/% ''~ ~'~ /_. - ADMINISTRATION 1. Permit fee attached ............... 4~././... . 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE 12. .~,' / 7'~tb 13. ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool. ~ ............... Well located proper distance from drilling unwary .... Well located proper distance from other wel~L ..... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... GEOL AREA ~ ~;~/'~-') UNIT# _/~_ %"-/?~'-'t,~ ON/OFF SHORE Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. Y N Y N N ..... ~ - ~ ~ - ~ 'Y(Y(Y~ U (~N GEOLOGY 30. 31. 32. APPR DATE 33. ,¢~ ~Y,/'~. O~ 34. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... ~ N 25. BOPEs, do they meet regulation ...... ~ .... '~,-~x'~, ~ N ~ -- . 26. BOPE press rating appropriate; test to ,~OC_JO .... psig~ 27. Choke manifold complies w/APl RP-53 (May 84) ~--,~.~'~ ~Y~.. N - 28. Work will occur without operation shutdown... ~ i i i ~ ~ i i ~ .1~ \",Xc-~Z,-., k~,..:k ,.t~,,....",.,r,-~ N,-_., \'-~O_x?~:>',, ' 29. Is presence of H2S gas probable ................. Y Permit can be issued w/o hydrogen sulfide meas,~s ..... (~ N - · · · Data presented onpotentialoverpressurezoneK.~.. ~ Y N ~__.,) ~'~r'C-~"~t,_ ~'.~-~'¢'~'~/~C~"~','~.~ ,~'~"~ ~'/ ~/r,r_~ ~,~-~... ~ ~'/~_~$~' · · · ' ...... Seismic analysis of shallow gas zones ............. A,/,,~ Y N Seabed condition survey (if off-shore) ............. ~',,~ Y N Contact name/phone for weekly progress reports [exploratory o,/~y~ Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (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 (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: i c:\msoffice\wordian\diana\checklist (rev. 02/17/00)