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183-116
ge Project Well History File~er Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~-(~;)--~- L I-~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: ._ OVE,~,ZED~ (Non-Scannable) [] Other: '~o NOTES: gs of various kinds ~ Other BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project 'Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ Scanning Preparation ~ x BY: BEVERLY BREN VINCENT SHERYL Production Scanning Stage 1 Stage 2 NO NO 2,32-- PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: .. YES / IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES BEVERLY BREN VINC~MARIA LOWELL (SCANNING I$ COMPLETE AT THIS POINT UNLESS SPECIAl. ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: General Notes or Comments about this file: Is/ Quality Checked III Itlllllllllll Ill UNSCANNED, OVERSIZED MATERIALS AVAILABLE: 7F2 // FILE # (/'e ( C/vi4/ /9/ l L U To request any /all of the above information, please contact: Alaska Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501. Voice (907) 279 -1433 1 Tax (907) 276 -7542 Fisher, Samantha J (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday,June 25, 2013 4:35 PM To: Fisher, Samantha J (DOA) Subject: FW: Sundry Cancellation -#313-106 for Baker Ba-27 (PTD 183-116) Guy Schwartz Senior Petroleum Engineer AOGCC SCANNED FEB 2 0 2014 907-444-3433 cell 907-793-1226 office From: Juanita Lovett [mailto:jlovettfthilcorp.com] Sent: Tuesday, June 25, 2013 4:18 PM To: Schwartz, Guy L(DOA) Subject: Sundry Cancellation - # 313-106 for Baker Ba-27 (PTD 183-116) Guy, Please cancel sundry#313-106 for Baker Ba-27. This project will not be completed so we wanted to close the sundry with the commission. Thank you, Juanita Lovett Sr.Operations/Regulatory Tech Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 Office: (907)777-8332 Email: Ilovett@hilcorp.com 1 • • OF r 0 V/77 s THE STATE Al Oil and Gas �� ®f l 1L1 1 � Commission �,�ser�a��r� �® �ssi ®n GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Q. Anchorage, Alaska 99501 -3572 A LAS - Main: 907.279.1433 Fax: 907.276.7542 Ted Kramer SCANNED MAR Z0 Sr. Operations Engineer _ ik Hilcorp Alaska, LLC 3 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Middle Ground Shoal Field, Undefined Gas Pool, MGS ST 17595 (Baker) 27 Sundry Number: 313 -106 Dear Mr. Kramer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this 11 y of March, 2013. Encl. • . ok....<) RECEIVED . e Eb•z STATE OF ALASKA ib/ ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 2 8 2013 APPLICATION FOR SUNDRY APPROVALS Q�� 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Welt] Suspend Approved Program ❑ Suspend ❑ Plug Perforations Perforate Pull Tubing Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter CasinE Other: Plug Backe Operator Name: Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to Drill Number. a Exploratory ❑ Development 0 . 183 -116 0 I3 Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. • Anchorage, Alaska 99503 50-733-20368-00 If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 (a)(4) MGS ST 17595 (Baker) 27 Will planned perforations require a spacing exception? Yes ❑ No 0 9 Property Designation (Lease Number): 10. Field /Pool(s): ADL0017595 • Middle Ground Shod Field / Undef Gas 11 • PRESENT WELL CONDITION SUMMARY 'I otal Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): _ 11,600 9,257 5,553 4,423 CIBP: SS 5,313' - Cement Plug LS 5,553 N/A Casing Length Size MD WO Burst Collapse Structural 185' 32" 185' 185' Conductor Surface 3,407' 13 -3/8" 3,407' 2,952' 2,730 psi 1,130 psi Intermediate Production 8,843' 9 -5/8" 8,843' 6,763' 6,820 psi 4,230 psi Liner 3,022' J 7" 11,592' 9,250' 9,690 psi 7,820 psi Perforation Depth MD (ft): Perforation De TV D (ft): Tubing Size: Tubing Grade. Tubing MD (ft): is • 5,492' - 5,538' J 4,386' - 4,414' 3 -1/2" dual N-80 SS 7,005' - LS 7,051' F ,ickers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A WA 11?. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program n t3OP Sketch n Exploratory n Stratigraphicn Development (✓l - Service n 14. Estimated Date for 15. Well Status after proposed work: 03/11/13 Su Commencing Operations: Oil ❑ Gas 0 f WD SPL ❑ Suspended ❑ 16. Verbal Approval: !:rate: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramer( hilcorD.corp Printed Name Ted Kramer Title Sr. Operations Engineer Signature ' i (. ! "f ` �� — Phone 907 - 777 -8420 Date 2128/2013 COMMISSION USE ONLY ( Conditions of approval: Notify Commission so that a representative may witness Sundry Number. :Iug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ., I ri :. RBDMS MAR 12 20t ';:pacing Exception Required? Yes ❑ "No i Subsequent Form Required: 4 . Liby // �/7 P `f � THPROVED Approved by: / ' 9 COMMISSIONER THE COMMISSS ION Date: 3 _ ll /3 �'' i v i � �• 6 • � � Submit Form and .. N0A2L Approved application is valid for 12 nths from the date of approval. chments in Duplicate a � v 3//e, A • • Well Prognosis Well: MGS ST 17595 -27 Hilcorp Alaska, LL Date: 2/28/2013 Well Name: MGS ST 17595 -27 (Ba -27) API Number: 50- 733 - 20368 -00 Current Status: SI Gas completion Leg: 2 Estimated Start Date: March 11, 2013 Rig: N/A Reg. Approval Req'd? 10 -403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 183 -116 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Reid Edwards (907) 777 -8421 (0) AFE Number: 1222507 Current Bottom Hole Pressure: 1,512 psi Calculated from 10/25/2012 fluid level (Using max .437 psi /ft gradient) Maximum Expected BHP: — 1,527 psi @ 3,394' TVD Using a .45 psi /foot Gradient Max. Allowable Surface Pressure: — 1,377psi (Based on 0.044 psi /ft gas gradient) Brief Well Summary This well was drilled and completed as an oil well in the Tyonek F & Hemlock in 1983 -1984. Subsequent workovers were performed in 1984 to stimulate the reservoir through reperfs, acidizing, and fracing these intervals. The workover in 1987 installed a hydraulic lift completion and added the Tyonek B, C, & D sands. The well was again worked over in 1991 to isolate the Tyonek F and Hemlock sands. A workover in 1993 raised the completion and added the Tyonek A perfs. In 2000 a variance to convert well to water injection was approved. Water injection was then halted in 2002. A thru- tubing abandonment of all open Tyonek oil sands was performed in 2005 and the well and isolation cement was pressure tested to 1,500 psi at that time. Last year, an attempt was made to recomplete the well to the T -40 Sand. Perforations were shot from 5,492' to 5,538' MD. These perforations tested wet. The proposed completion plan involves isolating the T -40 perfs from 5,492'- 5,538' with a bridge plug in the LS tubing and dump bailing a 25ft of cement on top of the plug. This approach provides a means of using one string for producing and utilizing the dormant string for diagnostic and remedial operations. Further advantages of the dual string completion will be realized during final abandonment of well to improve means of cement placement and pressure isolation capabilities Summary Procedure Abandonment of Tyonek Completion 1. Mob slick line, E -line, and test equipment to the Baker Platform. 2. RU slick line and set tubing stops in SS and LS and test to 5,000 psi. 3. Replace tree with like in kind to eliminate Teaks in current uniblock design. Pressure test tree to 5000 psi and remove tubing stops /plugs in LS and SS. 4. RU E line on LS and set expandable Bridge plug at — 5,400ft and dump bail 25ft of cement on CIBP. 5. RU pump on SS and load well for pressure test. Increase pump rate to 3 -4 BPM and record pressure at max rate. Perforate additional holes at 4,839'- 4,841' if not able to circulate at 3 BPM. 6. After loading hole with filtered sea water or 2% KCL. Pressure test casing to 1,500 psi for 30 minutes to confirm casing integrity and isolation of perforations at 5,492'- 5,538'. • • • Well Prognosis Well: MGS ST 17595 -27 Hilcorp Alaska, LL Date: 2/28/2013 7. RU E line & set cement retainer in SS @4,825'. 8. RU cementing equipment (complete with wiper plug head) on tubing with cement retainer and circulate cement plug to 3,000ft in 9 -5/8" annulus (volume req'd " 93bb1 or +/- 375sks) NOTE: launch wiper plug at tail of cement slurry and displace to retainer with ^'42bbI of filtered sea water or 2% KCI water. Slow cementing pumps to bump plug with minimum pressure over final displacement and bleed back 250 psi to confirm retainer holding. If retainer holds properly, bleed pressure on SS to 100 psi and shut in for minimum of 4 hrs. Do not bleed additional pressure during this 4 hr period unless it exceeds pressure at final displacement (temperature effects from cement curing) Completion in T -40 Sand interval 9. Retest casing if integrity test from step 5 did not pass. This test to 1,500 psi for 15 minutes will be performed by pumping in on casing with both tubing strings closed at the wellhead. Monitor pressure on LS and SS to observe for pressure communication from casing to production strings. NOTE: slight pressure on tubing strings should be expected from reverse ballooning. This pressure will stabilize shortly after reaching final casing pressure. 10. After MIT on casing is complete, bleed casing pressure back to 1,000 psi during cement curing period. 11. Bleed off pressure on both tubing strings to 100 psi and allow cement to cure. NOTE: If pressure on SS or LS tubing increases over 4 hr shut in, do not bleed off unless pressure exceeds 600 psi 12. RU E line on LS and run temperature survey to establish TOC in 9 -5/8" casing. 13. After cement curing is complete proceed to step 15. 14. Bleed off pressure on SS, LS, and Casing. 15. Swab down LS to '" 2,200ft to achieve underbalance of +/ -1000 psi. 16. RU E line on LS and RIH with oriented perforating system and map tubulars at perforating targets per attached wellbore diagram. Perforate 4,017'- 4,027' for production test and evaluate. ✓�P`ei &Cr 17. If production is sustained, run surveys in SS to evaluate fluid movement behind 9 -5/8" casing. 18. If flow of water behind casing is detected, remedial work will be conducted for isolation (cement squeeze operations etc) by utilizing the utility tubing string in the well. C A S OU., .. / � �'"�''" .4- ' - r -L- " � " � 19. If isolation of the producing zone is not required, the perforating program will be expanded to those intervals proposed on the attached wellbore diagram. 20. Flow test well to establish steady flowing wellhead pressure and set operating pressures on SSSV. 21. When recompletion work is complete, RU E line on production tubing and RIH with SSSV (Weatherford PB valve or equivalent) on E -line set packer at +/- 302ft RKB. 22. RD E line 23. Demob well service equipment. 24. Turn well over to production. Attachments: 1. Tree Schematic 2. As -built Well Schematic 3. Proposed Well Schematic • • Well Prognosis Well: MGS ST 17595 -27 Hilcorp Alaska, LLB Date: 2/28/2013 Baker Platform Tubing hanger, dual, CIW- BA-27 DCB. 11 X 314 eue lift x 13 3/8 X 95/8X3 3 /7IBTsusp,WI3 "'type 3112 H BPV profile, 411116 extended neck Companion flange, 3 118 5M5 bolt X3V; i ti i II .M — Mal r Tree. Dual Block CIW-F, _, 11 5M FE X 3 118 5M , �lr , single master and swab, 3 118 5M wing, prepped fi +� 3" nom CIW seal pockets .1 NI r r r I: polli Tubing head, CIW -DCB, in ltal 13 5/8 3M X 11 5M, w12- III 1 — � ' 2 1116 5M SSO, X-bottorn r� Valve, CIW -F, 2 1116 5vl prep, 1 ' VR profile ■ ' ' " Ili - FE, HWO. AA N style lockpins oar III OTY 2 :1-.1 1 01 ail (r Il . -4„.„ , ..,...„ . lei mull !000mt Casing head, CIW -WF, �� 135?83Pv1X133?BSOt "J, IIII �' Valve, CIW -F, 2 1/16 3M w +2- 21r165MEF0. in j [ jP 11 FE, f'* ;} OTY 2 illir ) 16-iliejiliiii -. 4.0 - ji - T 'ft" 111111 lir" - i , 4 H • Cook Inlet Basin ... Schematic Well No: Ba -27 tlilcorp Alaska, LLC Last Completed: 2 -10 -1993 RKB: MSL = 101' ADL: 17595 PTD: 183 -116 API: 50- 733 - 20368 -00 Mudline= 203' Water Depth= 102' Leg 2, Slot 5 MGS St 17595 27 s t # f" Casing Detail ' Cement 32" 1 Size Type Wt /Grade/ Conn ID Top Btm Sacks CMT Top t� a s f, 32" Structural Surf 185 MS 54.5 / 68 / 61# 2,500 + Surf Top s " • i , 1 , ... 13 -3/8" Surface 12.415 Surf 3,407' s 4 . «, K55/N80, BTC 560 Job 53.5, 595, BTC 8.535 Surf 309' ',"3„„* _ iA 40, 595, BTC 8.835 309' 3,547' .l 9 -5/8" Intermediate 43.5, S95, BTC 8.755 3,547' 4,995' 1,400 6,470 CBL ■x ",'"j 47, S95, BTC 8.681 4,995' 6,659' - .V i 53.5, 595, BTC 8.535 6,659' 8,843' r� ,. "' • 29, HC95, BTC 6.184 8,590' 11,266' 7" Liner 925 35, 595, BTC 6.004 11,266' 11,592' 13 Short String 3407' 1• Size Type Wt /Grade /Conn ID Top Btm Tubing Patch 5,033' - 5043.5' 3 -1/2" Prod Tubing 9.2, N80, w /Special Cl Cplgs 2.992 31' 7,005' LS Tag cement Long TDS String at 5,553'. Tubing Cala TOC �n 9-5/8 enucivae punches 5,035' Size Type Wt /Grade /Conn ID Top Btm - 5,040'. 8/14/05 Tubing punches CIBP in ss @ 5,313 3 -1/2" Prod Tubing 9.2, N80, TDS w/ Special CI Cplgs 2.992 31' 7,051' for 2nd stage cement plug at ■4 4 " - 6,149'- 8,155'. SS: Tag cement Jewelry Detail at 5,336'. Tubing Perfoations punches 4,839' - # Depth Length ID Item 5,492- 5,538' ♦ 4,841'. (8/18/05) TOC CBL Long String 6470' A . Dual 11" CIW -DCB Hanger, 3" Type "H" 2 1 s 1 31 2.992 BPV profile, 3 -1/2" Butt Dwn s ;; ;; 2 7,014' 2.42 Crossover, 3 -1/2" EUE x 3-1/2" 3 7,017' 22.63 KOBE 3" B cavity 4 4 7,039' 1.72 Crossover, 3 -1/2" Butt x 3 -1/2" EUE 5 _ _ ©6 --- - 5 7,041' 9.4 2.992 Pup joint 3 -1/2" TDS tubing Oil Top G &G +_ . 7100' 6 7,051' 0.76 WREG Sqzd Perfs Short String , . , 7105'- 8511' A 5,313' CIBP B 7,006' 0.74 Crossover, 3 -1/2" TDS x 2 -3/8" EUE TOL al 8590' C 7,006' 10.07 Pup Joint 2 -3/8" 4.6# N80 tubing 9 -5 /8" History 8844' • BPg 9950' 2010 -Well skipped during well circulation work since records show 9.8 ppg brine circ in 2005 and no pressure on tubing or annulus 2005 - Bundle test of LS, SS, and annulus to 1500 psi for 30 min (AOGCC witness) - good. - Perforations Open Perfs • T_ 9988' -11114' Top(MD) Btm(MD) Top(TVD) Btm(TVD) Detail - 7,105' 8,511' 5,484' 6,513' Squeezed iiP `, 9,968' 11,114' 7,707' 8,807' Some squeezed & all isolated 115 • - . � by BP at 9,950' KB � �� 5,492' 5,538' 4,386' 4,414' Open PBTD = 5553' TD = 11600' MAX HOLE ANGLE = 54.5 @ 5600' MD Revised By: JLL 01 -17 -2013 • • • Cook Inlet Basin PROPOSED Well No: Ba -27 Hilcorp Alaska, LLt. Last Completed: 2 -10 -1993 RKB: MSL = 101' ADL: 17595 PTD: 183 -116 API: 50- 733 - 20368 -00 Mudline= 203' Water Depth= 102' Leg 2, Slot 5 MGS St 17595 27 1 L-J f 1 Casing Detail Size Type Wt/ Grade/ Conn ID Top Btm Cement CMT Top 32" Sacks 32" Structural Surf 185 MS A 13-3/8" Surface 54.5/68/61 #, K55/N80, BTC 12.415 Surf 3,407' 2,500+ Surf Top 560 Job 53.5, 595, BTC 8.535 Surf 309' 40, 595, BTC 8.835 309' 3,547 TOCCBL ' ..� 3000. 9 - 5/8" Intermediate 43.5, S95, BTC 8.755 3,547' 4,995' 1,400 6,470 CBL ' " , *" 47, S95, BTC 8.681 4,995' 6,659' 53.5, 595, BTC 8.535 6,659' 8,843' 7" Liner 29, HC95, BTC 6.184 8,590' 11,266' 925 35, S95, BTC 6.004 11,266' 11,592' Short String • 3 -3/8' Size Type Wt /Grade /Conn ID Top Btm 3,407' 3 - 1/2" Prod Tubing 9.2, N80, TDS w/ Special CI Cplgs 2.992 31' 7,005' Tubing Patch B 5.033' - 5043 -5' ; Long String LS: Tag cement Size Type Wt /Grade /Conn ID Top Btm punches 5,,0035' pun c3 3 - 1/2" Prod Tubing N80, TDS Special Cl Cplgs 2.992 31' 7,051' tes � ro g 9.2, N w/ pec - 5,040'. 8/14/05 �" Cal TOC in 3543' Tubing punches a w�5,222' Jewelry Detail for 2nd stage D `' O Cement Plv cement plug at g # Depth Length ID Item 6,149' - 6,155'. SS: ag cement in 1b at 5,336'. Perfoations 2 'A Tub gpunches Long String 5,492'5,538' ♦ 4,839' - 4,841'. (8/16/05) Dual 11" CIW -DCB Hanger, 3" Type "H" TOC CBL - 1 31' 2'992 BPV profile, 3 -1/2" Butt Dwn 6,470' 2 ±7,014' 2.42 Expandable Bridge Plug �. 3 7,017' 22.63 KOBE 3" B cavity e .. 4 7,051' 0.76 WREG ! Short String 4 • �® ., , A ±310' Weatherford "PB" SSSV Assy. Oil Top GBG B ±4,824' Cement Wiper Plug 7100' C ±4,825' Cement Retainer Sqzd Pens 7105 -8517 D 5,313' CIBP Perforations TOL @ 8590' . ' Top(MD) Btm(MD) Top(TVD) Btm(TVD) Detail 9 -5/8 " • , . 7,105' 8,511' 5,484' 6,513' Squeezed 8844' . BP@ 9950' 9,968' 11,114' 7,707' 8,807' Some squeezed & all isolated by BP at 9,950' KB 5,492' 5,538' 4,386' 4,414' Open ±4,017' ±4,048' ±3,372' ±3,394' Future Open Perfs ±3,782' ±3,800' ±3,208' ±3,220 Future 9968' - 11114' • ±3,617' ±3,636' ±3,094' ±3,107' Future • • 11592' ' PBTD = 5553' TD = 11600' MAX HOLE ANGLE = 54.5 @ 5600' MD Revised By: TDF 2/28/2013 • • Schwartz, Guy L (DOA) From: Ted Kramer <tkramer @hilcorp.com> Sent: Friday, March 08, 2013 10:46 AM To: Schwartz, Guy L (DOA) Cc: Robert Kendrick - (C) Subject: RE: Baker Platform Well # 27 Sundry 313 -024 (ptd 183 -116) Guy, We are amenable to trying that. We may try to shoot with a lesser penetrating charge to penetrate the casing, then try to circulate to surface. If we cannot establish circulation, then shoot deeper penetrating charges to swab back. My concern is that I would not want to shoot the deepest charge I can, and then pump cement into it to circulate back to surface. We need to be able to shoot past the cement after pumping. Ted Kramer Sr. Operations Engineer Hilcarp Alaska, LLC. 0 907- 777 -8420 C 985- 867 -0665 From: Schwartz, Guy L (DOA) [masito: wy.schwartz_.d al ska.gov] Sent: Friday, March 08, 2013 10:36 AM To: Ted Kramer Cc: Robert Kendrick - (C) Subject: RE: Baker Platform Well # 27 Sundry 313 -024 (ptd 183 -116) Ted, Rob: I have reviewed the sundry... one suggestion is to attempt to establish circulation immediately after perfing the lower zone ( 4017 -4027) up to the OA at surface. This may not be practical but it might be worth trying before swabbing in the well. If circulation can be established then cement can be placed up to the OA shoe and then reperf the zone. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907 - 444 -3433 cell 907- 793 -1226 office 1 f ' ' • . From: Ted Kramer [z� a+it tKr -ariit r c tticcr .coal] Sent: Saturday, March 02, 2013 9:12 AM To: Schwartz, Guy L (DOA) Cc: Robert Kendrick - (C) Subject: Baker Platform Well # 27 Sundry 313 -024 Guy, Thanks for taking the time to talk to Bob Kendrick and myself on Friday March 1, 2013 about the above well. As per our conversation We would like to do the following regarding the well Sundry: 1. Withdraw the current application for Sundry #313 -024 in favor of the new application sent over via courier with the following additions: a. Conduct an MITOA on the 9 -5/8" X 13 -3/8" annulus to 400 psi. (See detail in the discussion below). Should the well fail the MITOA, then a PIR will be established and mitigation steps explored. Discussion Research of the 13 -3/8" casing shoe test on the Ba 27 revealed that a test was done on 10 -1 -83 to an equivalent mud wt of 13.2 ppg. The mud wt in the hole when the 9 -5/8 casing was cemented on 12/03/83 was 10.3 ppg. Therefore the maximum surface pressure for the MITOA test should be (13.2- 10.3) *.052 *2946 = 444 psi so we do not exceed the original shoe test pressure. Research of the bleed history of the Ba -27 revealed no indication that the well has built up pressure and been in any sort of a periodic bleed down program. Thanks again for your time. It helps to have a face to face dialogue when discussing less conventional means of working on wells. I know I appreciate it and Bob does as well. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907- 777 -8420 C 985 - 867 -0665 2 RECEIVED STATE OF ALASKA JAN g 2013 ALO OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate 0 OtheC Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extensiot❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended We❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑ Exploratory ❑ 183 -116 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service El 6. API Number: Anchorage, AK 99503 50- 733 - 20368 -00 7. Property Designation (Lease Number): 8. Well Name a Number: ADL0017595 MGS ST 17595 (Baker) 27 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): _ Middle Ground Shoal / A Oil, B C & D Oil, E F & G Oil, Undefined Gas 11. Present Well Condition Summary: Total Depth measured 11,600 feet Plugs measured SS- CIBP5,313'& feet LS - Cement Plug @ F FF4 true vertical 9,257 feet Junk measured N/A feet Effective Depth measured 5,553 feet Packer measured N/A feet true vertical 4,423 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural 185' 32" 185' 185' Conductor Surface 3,407' 13 -3/8" 3,407' 2,952' 2,730 psi 1,130 psi Intermediate Production 8,843' 9 -5/8" 8,843' 6,763' 6,820 psi 4,230 psi Liner 3,022' 7" 11,592' 9,250' 9,690 psi 7,820 psi Perforation depth Measured depth 5,492 - 5,538 feet True Vertical depth 4,386 - 4,414 feet Short String 3 -1/2" N -80 7,005' (MD) 5,407' (TVD) Tubing (size, grade, measured and true vertical depth) Long String 3 -1/2" N -80 7,051' (MD) 5,443' (TVD) Packers and SSSV (type, measured and true vertical depth) Packer - N/A SSSV - N/A 12. Stimulation or cement squeeze summary: t� Intervals treated (measured): SCANNED MAR 2013 N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ -"' Service0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ .,Gas U WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -352 Contact Ted Kramer Email tkramerphilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature £j Phone 907 777 -8420 Date 1/17/2013 Form 10-404 Revised 10/2012 RB®MS JAN 8 L01 6 Z' 774 g . Submit Original Only • r • • Cook Inlet Basin Schematic Well No: Ba -27 Ililcorp Alaska, LLC Last Completed: 2 -10 -1993 RKB: MSL = 101' ADL: 17595 PTD: 183 -116 API: 50- 733 - 20368 -00 Mudline= 203' Water Depth= 102' Leg 2, Slot 5 MGS St 17595 27 1 C___J L-J - I ..: Casing Detail Size Type Wt/ Grade/ Conn ID Top Btm Cement CMT Top 32" Sacks 32" Structural Surf 185 MS 13 -3/8" Surface 54.5/68/61 #, 12.415 Surf 3,407' 2,500 + Surf Top K55 /N80,BTC 560 Job 53.5, S95, BTC 8.535 Surf 309' • 40, S95, BTC 8.835 309' 3,547' 9 -5/8" Intermediate 43.5, S95, BTC 8.755 3,547' 4,995' 1,400 6,470 CBL 47, S95, BTC 8.681 4,995' 6,659' 53.5, S95, BTC 8.535 6,659' 8,843' 29, HC95, BTC 6.184 8,590' 11,266' 7" Liner 925 Ael 35, 595, BTC 6.004 11,266' 11,592' 13 - 3/8 ' , Short String 3407' v Size Type Wt /Grade /Conn ID Top Btm Tubing Patch 5,033'- 5043.5' 3 -1/2" Prod Tubing 9.2, N80, TDS w/ Special CI Cplgs 2.992 31' 7,005' at 5 ,55 .Tabin Long String at 5,553'. Tubing Calc Toc in 9 - 5/6" punches 5,035' = a " ° °Iu e 5,222 Size Type Wt /G rade /Conn ID Top Btm - 5,040'. 8/14/05 A= Tubing punches CIBP In 55 @ 5.313 3 -1/2" Prod Tubing 9.2, N80, TDS w/ Special CI Cplgs 2.992 31' 7,051' for 2nd stage 4- cement plug at 6,149'- 6,155'. SS: Tag cement Jewelry Detail _. at 5,336'. Tubing Perfoations punches 4,839'- # Depth Length ID Item 5,492 - 5,538' ♦ 4,841'. (8/16/05) roc CBL Long String 6470' A 1 31' 2 992 Dual 11" CIW -DCB Hanger, 3" Type "H" 2 •U .B' ,.. BPV profile, 3 -1/2" Butt Dwn • l II 3 2 7,014' 2.42 Crossover, 3 -1/2" EUE x 3 -1/2" 3 7,017' 22.63 KOBE 3" B cavity 4 4 7,039' 1.72 Crossover, 3 - 1/2" Butt x 3 -1/2" EUE 6 ' ■ 5 7,041' 9.4 2.992 Pup joint 3 -1/2" TDS tubing Oil Top G &G s ' 7100' 6 7,051' 0.76 WREG ! - Sgzd Perfs ;; 7105'-8511 Short String . ' A 5,313' CIBP `'' ` B 7,006' 0.74 Crossover, 3 -1/2" TDS x 2 -3/8" EUE TOL @ 8590' 1 . , , C 7,006' 10.07 Pup Joint 2 -3/8" 4.6# N80 tubing 9-5/8"2, History 8844' , BP@ 9950' 2010- Well skipped during well circulation work since records show 9.8 ppg brine circ in 2005 and no pressure on tubing or annulus 2005 - Bundle test of LS, SS, and annulus to 1500 psi for 30 min (AOGCC witness) - good. Perforations Open Perfs 9968'- 11114' Top(MD) Btm(MD) Top(TVD) Btm(TVD) Detail y 7,105' 8,511' 5,484' 6,513' Squeezed 7 >> 9,968' 11,114' 7,707' 8,807' Some squeezed & all isolated 11592' L ' by BP at 9,950' KB 5,492' 5,538' 4,386' 4,414' Open ''V PBTD = 5553' TD = 11600' MAX HOLE ANGLE = 54.5 @ 5600' MD Revised By: JLL 01 -17 -2013 110 it r Alaska, LLC � .. H cop Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BA -27 50- 733 - 20368 -00 183 -116 10/9/12 10/25/12 10/09/2012 - Tuesday Rig up slickline. RIH w/ 2.85" gauge ring and tagged TOC at 5,546' RKB (wlm). POOH. RIH with wireline brush and brush tubing from 5,000' RKB to 5,100' RKB. POOH. Secure well and shut down for the night. Will be moving to Ba -18 around 6 am. 10/11/2012 -Thursday Attempt to repair swab valve on LS. Valve has alot of cement in it and wore out. Put another swab valve on top of tree for temp repair. Will see about getting a new tree after testing the well. Hook up the tri -plex pump rented from Atigun and blew oring out of filter with trying to pump on well. Called Atigun and found out they do not put check valves on any of their test pumps. Will be sending pump in. Hooked up diaphragm pump and finished filling up well. Well held approx 5 bbls total to fill. Hook up high pressure pump and bundle tested the LS, SS and 9 -5/8" annulus to 1,500 psi for 30 min. Charted test and faxed it to main office. Pressure held over night also. Sent everyone in at 19:30 hrs except Ken and Jamie. They stayed and got the test on LSW. 10/12/2012 - Friday RU lubricator. RIH with 1- 11/16" CBL /GR /CCL in LS down to 400'. Tools shorted out. POOH. RIH with 1- 11/16" CBL /GR /CCL tool in LS to 1,200'. RIH with 1- 11/16" CBL /GR /CCL tool, tie into Halliburton Therm Multigate Decay Log dated 13- Feb -91 and tag TOC in LS at 5,543'. Having trouble with CBL. Got a GR log. POOH. Will trouble shoot later this morning. Shut down for night. 10/13/2012 - Saturday RIH with CBL /GR /CCL, Halliburton Therm Multigate Decay Log dated 13- Feb -91, and tag at 5543'. Determined that it had good cement to 5,460'. Poor to none to 5,362' and no cement to surface. Sent data to main office. Decided to run a 15' patch instead of a 10' patch. The top perf is approx 4' beneath tubing collar and cannot set the tubing patch top slip in a collar. With a 15' patch we can set top slips above collar and still cover the 5' of tubing punches. Make up 2.75 "x10' Owens patch. Rig lubricator back up on LS. RIH slow w /Owens tubing patch and tag cement at 5,537' RKB (wlm). Logged up to 4,950' and got on depth with collar at 5,001'. Chevron morning report dated 8/14/05 stated that APRS tied into that collar and dropped down and tubing punched from 5,035' to 5,040'. We could see the tubing punch holes on this log. Logged up and put top of patch at 5,033.5' (tubing collar at 5,032' and can't set patch slips in collar) and bottom of patch at 5,043.5'. Set the patch. Rig down lubricator and secure well. 10/14/2012 - Sunday Got good solid pressure test on the patch (LS) of 1,500 psi. Charted test and faxed to consultant in main office. Slickline on board. SIMOPS, PTW, JSA. Rig up lubricator. RIH with 2.999 swap cups on LS and swab well down to 1,580'. Changed out swab cups twice. POOH. Rig down slickline off well and secure. PTW and JSA. Mobe and rig up E -Line equipment over to well. Pressure test lubricator to 250 psi low and 2,500 psi high. Had trouble keeping trash out of pump. Doesn't take much to keep from pumping. Will definitly find a tri -plex pump for next job. RIH w/ 2 -1/8" x 20' HC, 6 spf, 60 deg phase perf gun and tie into Halliburton Therm Multigate Decay Log dated 13- Feb -91. Went thru tubing patch fine (2.33" ID thru Patch). Pick back up and had trouble getting thru it. Went thru patch 2 more times without any trouble. Went down and tagged at 5,516' (lost approx 22' of hole). That would have gave us just 24' of perf instead of 46'. We tagged with CBL log at 5,538' before we set patch and swabbed well. Started out of hole and got hung up in patch. Worked tools and finally got loose. Seems like maybe cement pieces or something got on top of the rope socket and wedge us in the patch. Pulled 2,800 Ibs over string wt to get loose. POOH and disarm perf gun. Talked to consultant in main office about forward plan. Rigged down lubricator. Hilcorp Alaska, LLC • .. Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BA -27 50- 733 - 20368 -00 183 -116 10/9/12 10/25/12 10/16/2012 - Tuesday Rig up lubricator. RIH with 2.50" GR and tag top of patch at 5,052' RKB. Ran this so we would have a reference point when we start bailing. POOH. E -line logged top of patch at 5,039' when running perf gun. RIH w/ 2" x 5' DD bailer and tag at at 5,516' after correlating back to E -line measurements. Hit bridge twice and went down to 5,543'. POOH. Had cement mixed with fluid (mush). RIH w/ 2" x 5' DD bailer and tag at at 5,543' after correlating back to E -line measurements. Made 6' after bailing about 15 minutes and then didn't make any more hole for another 15 minutes. Depth now is 5,549'. POOH. RIH w/ 2 -1/4" x 11' DD bailer and tag fill at 5,549'. Bailed on fill and didn't make any hole. POOH. Bailer had a little cement mush and chunks of hard cement. Looks like we are bailing on TOC. NOTE: Fluid level is at 1,560' RKB. Rig down slickline. Wait on E -line. Rig up E -line. Pressure test lubricator to 250 psi low and 2500 psi high. RIH w/ 2 -1/8" x 20' HC, 6 spf, 60 deg phase perf gun and tie into Halliburton Therm Multigate Decay Log dated 13- Feb -91. Spot perf gun from 5,538' to 5,518' per Final Approved Perforation Request Form dated 10/11/2012 submitted by consultant in main office. Tubing pressure 0 psi. Fired gun and tubing pressure still zero. Lost 200 Ibs on wt indicator when fired and regained after picking up. POOH. RIH w/ 2 -1/8" x 20' HC, 6 spf, 60 deg phase perf gun and tie into Halliburton Therm Multigate Decay Log dated 13- Feb -91. Spot perf gun from 5,518' to 5,498' per Final Approved Perforation Request Form dated 10/11/2012 submitted by consultant in main office. Tubing pressure 0 psi. Fired guns and no pressure change. POOH. RIH w/ 2 -1/8" x 6' HC, 6 spf, 60 deg phase perf gun and tie into Halliburton Therm Multigate Decay Log dated 13- Feb -91. Spot perf gun from 5,498' to 5,492' per Final Approved Perforation Request Form dated 10/11/2012 submitted by consultant in main office. Tubing pressure 0 psi. Fired guns and no pressure change. POOH. Rig down E -line. Rig up slickline. RIH w/ 2.99" swab cups and tag fluid at 349' RKB. Made a few swab runs and then found out that the 9 -5/8" and the short string was on a vacumn. 10/17/12 - Wednesday Wait on slickline plug. Move off LS. Rig up on short string. RIH w/2.80" GR and tag TOC at 6,268' RKB (Should be at 5,336') POOH. RIH with braided line brush and brush tubing at 5,300' to 5,330' several times RKB, POOH. RIH w /AD2 stop, then the plug and then the A stop. Set the plug at 5,313' RKB on SS. Pumped 5 bbls inlet water and the results are: 9 -5/8" went from vac to 30 psi, SS went from vac to 20 psi and LS went from vac to 1 psi. Called engineer and told to pump 10 bbls into 9 -5/8" casing. 9 -5/8" went to 50 psi, SS went to 45 psi and LS went to 6.8 psi. Bled 9 -5/8" casing to 0 psi, SS went to 10 psi and LS went to 5.7 psi. Secured well. 10/20/2012 - Saturday Rig up on LS. Pressure test to 250 low and 1500 psi high. Bled SS to 0 psi /vacumn change. Found fluid level at 376'. Swab to 1,050'. Shut down for dinner. Strap tank and had recovered 19 bbls (44 bbls since we started a few days ago). This is after 13 runs. RIH and found fluid level at 800'. 250' fluid rise after 45 min. SS and 9 -5/8" on a vac. Called Chad and continue swabbing for for a total of 19 runs. Fluid level at 870' when shut down for the night. Rig down lubricator and secure well. Blow down lines. 10/21/2012 - Sunday Rig up slickline and tag fluid level at 680'. Start swabbing. Slickline lost some tool wt, so pulled up in lubricator. Laid down lubricator. Rigged up recovery tool to attempt recovery of lost tools, RIH with same. Got hold of tool string at top of patch in long string. Starting back out slowly pulling 1,300 to 1,500Ibs. W/L back on surface with lost tools, rigged down off well. Secured test skid and blew down lines from BA -27 to Rain for Rent tank. 10/25/2012 - Thursday RIH with swab cups to 940' KB. Tagged fluid and started swabing. LD lub, cut wire, rehead and locate ball valve closer to tree. Resume swab. LD lubricator to cut wire and rehead @ 1700 hrs. Swab to 1,950' KB. Talked to town and told them still no gas. Decided to SD WL work until we can determine next plan. RD WL and rig equipment to ship to town on next boat. Wait on helicopter. • • RECEIVED • STATE OF ALASKA JAN 18 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon Plug for Redril 0 Perforate New Pod ❑ Repair We0 Change Ap oved Program ❑ Suspend ❑ Plug Perforations [� Perforate 0 • Pull Tubing Time Extension ❑ Operations Shutdowt ❑ Re -enter Susp. Wel ❑ f Stimulate ❑ Alter Casin] Other. ❑ 2. Operator Name: Hilcorp Alaska, LLC 4. Current WeN Class: 5. Permit to r Number � Numbe Exploratxy ❑ Development ID 183-116 • 3. Address: 6. API ber. 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service 0• Anchorage, Alaska 99503 50-733-20 00 • 7. If perforating: 8. Well Name - Number. 1 What Regulation or Conservation Order governs well spacing in this pool? 20 MC 25.055 (aX4) MGS ST 17595 (Baker) 27 • I Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0017595 - Mid • e ran Shoal Field / def Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): `lugs (meas ). Junk (measured): • 11,600 9,257 • 5,553 4,423 CIBP: SS 5, 3' - C ent Plug LS 5,553 N/A Casing Length Size MD TVD Burst Collapse Structural 185' 32" 185' 185' Conductor r - Surface 3,407' 13 -3/8" 3,407' 952` 2,730 psi 1,130 psi Intermediate ` Production 8,843' 9 -5/8" 8, ; ' ' 6, 6,820 psi 4,230 psi Liner 3,022' 7" 11,59 I 9,2 9,690 psi 7,820 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Si - • i ubing Grad : Tubing MD (ft): • 5,492' - 5,538' 4,386' - 4,414' \i V ce /2' • ual i N -80 SS 7,005' - LS 7,051' Packers and SSSV Type: Packers a d ' D (ft) -nd TVD (ft): N/' N/A 12. Attachments: Description Summary of Proposa 1 13. ell of - -r proposed work: 2 Detailed Operations Program ❑ BOP Sketch • Ex. orato VII Stratigraplit0 Development ❑ Service El 14. Estimated Date for 15. - tali after proposed work: 02/01/ Gas G • WDSPL ❑ Suspended ❑ Commencing Operations: Oil ❑ as 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and corre o the best of my knowledge. Contact Ted Kramer Email tkramerehilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature - �'�/j� - L.. Phone 907- 777 -8420 Date 1/18/2013 COMMISSION USE ONLY .... Conditions of approval: Notify Commissio • so that a representative may witness """ Sundry Number: 316 - 02q Plug Integrity ❑ BOP -st ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: % SCANNED MAg 1. 3 2013 RBD�IS MAR 0 7101 Spacing Exception Required? Yes ❑ No El Subsequent Form Required: APPRQVED BY - - -- • Approved by: COMMISSIONER T1'COMMISSION Date: RI GINAL / /e '.° mit Form and \ ° Form 10 (Revised 10/2012) Approved application is valid for 12 months from the date of approval. - Attachments in Duplicate Z � • Well Prognosis Well: MGS ST 17595 -27 Hilcorp Alaska, LL Date: 1/18/2013 Well Name: MGS ST 17595 -27 (Ba -27) API Number: 50- 733 - 20368 -00 Current Status: SI Gas completion Leg: 2 Estimated Start Date: February 1, 2013 Rig: N/A Reg. Approval Req'd? 10 -403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 183 -116 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Reid Edwards (907) 777 -8421 (0) AFE Number: 1222507 Current Bottom Hole Pressure: 1,512 psi Calculated from 10/25/2012 fluid level (Using max .437 psi /ft gradient) Maximum Expected BHP: — 1527 psi @ 3,394' TVD Using a .45 psi /foot Gradient Max. Allowable Surface Pressure: — 1,377psi (Based on 0.044 psi /ft gas gradient) Brief Well Summary This well was drilled and completed as an oil well in the Tyonek F & Hemlock in 1983 -1984. Subsequent workovers were performed in 1984 to stimulate the reservoir through reperfs, acidizing, and fracing these intervals. The workover in 1987 installed a hydraulic lift completion and added the Tyonek B, C, & D sands. The well was again worked over in 1991 to isolate the Tyonek F and Hemlock sands. A workover in 1993 raised the completion and added the Tyonek A perfs. In 2000 a variance to convert well to water injection was approved. Water injection was then halted in 2002. A thru- tubing abandonment of all open Tyonek oil sands was performed in 2005 and the well and isolation cement was pressure tested to 1500psi at that time. Last year, an attempt was made to recomplete the well to the T -40 Sand. Perforations were shot from 5,492 to 5,538' MD. These perforations tested wet.. The current recompletion plan involves cutting the current two tubing strings and removing them. A CIBP will then be set isolating the T -40 perfs. A new completion will then be ran so that other potential intervals can be tested up hole. Brief Procedure: 1. Mob slickline, a -line, a casing Jack, and test equipment to the Baker Platform. 2. Pressure test BOP to 250psi low /2500psi high. 3. RU E -line. RIH in each string and cut tubing at 5,000 ft ( + / -). RD E -line. 4. RU casing Jack and POOH with same. 5. RU E -line. RIH with CIBP to 4,950' ( + / -) and set. (Note: casing was pressure tested to 1,500psi for 30 Min. in phase 1.) Dump Bail 25' of cement on top of CIBP. Fill hole and pressure test plug to 250 psi for 10 minutes. 6. RIH with EZ dril Retainer and TCP guns hung below on a -line and set same 4010' (+1-). 7. PU RIH w/ Workstring and sting into retainer. Pressure up and fire guns. 8. RIH with jet cutter and drop guns. Establish PIR into perforations. Check for circulation in 9 -5/8" X 13 -3/8" annulus. 9. Pump Cement squeeze into perfs to isolate perf interval. Pull out of stinger. Reverse out excess cement. POOH with workstring. • • Well Prognosis Well: MGS ST 17595 -27 Hilcorp Alaska, LL L✓( — Date: 1/18/2013 10. PU down hole motor on work string. RIH to top of retainer. Drill up EZdril retainer and cement. POOH with Motor. 11. PU completion packer on completion string. RIH and set packer at 3,567' 12. RU E line. RIH with Perforation guns. Place guns on depth and perforate 4,017 — 4048'. Pooh with guns. 13. Turn well over to production. Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. Baker Reactivation Operation and Development Plan • • k et Schematic Well C oo No Ilacorl, Alaska, LLC Last Completed: 2 -10 -1993 RKB: MSL = 101' ADL: 17595 PTD: 183 -116 API: 50- 733 - 20368 -00 Mudline= 203' Water Depth= 102' Leg 2, Slot 5 MGS St 17595 27 « " 1 11-1 %' Casing Detail Cement 32" Size Type Wt/ Grade/ Conn ID Top Btm Sacks CMT Top I 32" Structural Surf 185 MS 13 -3/8" Surface 54.5/68/61 #, 12.415 Surf 3,407' 2,500+ Surf Top K55/N80, BTC 560 Job 53.5, S95, BTC 8.535 Surf 309' 40, S95, BTC 8.835 309' 3,547' 9 -5/8" Intermediate 43.5, S95, BTC 8.755 3,547' 4,995' 1,400 6,470 CBL 47, S95, BTC 8.681 4,995' 6,659' 53.5, S95, BTC 8.535 6,659' 8,843' 29, HC95, BTC 6.184 8,590' 11,266' 7" Liner 35, 595, BTC 6.004 11,266' 11,592' 925 13 Short String 3407' Tubing Patch Size Type Wt /Grade /Conn ID Top Btm 5,033' - 5043.5' 3 - 1/2" Prod Tubing 9.2, N80, TDS w/ Special CI Cplgs 2.992 31' 7,005' 5 cement I Long String at ,55 at 5,553'. Tubing Cale 7oC in ,222 xnuulus@ punches 5,035' Size Type Wt /Grade /Conn ID Top Btm - 5,040'. 8/14/05 Tubing punches = CIBP inSS @ 5,313' 3-1/2" Prod Tubing 9.2, N80, TDS w/ Special CI Cplgs 2.992 31' 7,051' for 2nd stage cement plug at ■ 4 4- 8,149'- 8,155'. SS: Tag cement Jewelry Detail at 5,338'. Tubing Pertoations punches4,839'- # Depth Length ID Item 5,492 - 5,538' ♦ 4,841'. (8/18/05) TOC CBL Long String 6470' --.1--, A 1 31' 2.992 Dual 11" CIW -DCB Hanger, 3" Type "H" 2 g BPV profile, 3 -1/2" Butt Dwn 3. l . 2 7,014' 2.42 Crossover, 3 -1/2" EUE x 3 -1/2" 3 7,017' 22.63 KOBE 3" B cavity a' 4 7,039' 1.72 Crossover, 3 -1/2" Butt x 3 -1/2" EUE 5 ' -. _ _6 -. - _ 5 7,041' 9.4 2.992 Pup joint 3 -1/2" TDS tubing Oil Top G &G 7100' - 6 7,051' 0.76 WREG • ' Sqzd Perts Short String - 7105'- 8511' ' A 5,313' CIBP , • . • B 7,006' 0.74 Crossover, 3 -1/2" TDS x 2 -3/8" EUE TOL (8J 8590' C 7,006' 10.07 Pup Joint 2 -3/8" 4.6# N80 tubing 9 - 518" History ` BP@ 9950' 2010 - Well skipped during well circulation work since records show 9.8 ppg brine circ in 2005 and no pressure on tubing or annulus 2005 - Bundle test of LS, SS, and annulus to 1500 psi for 30 min (AOGCC witness) - good. Perforations Open Perfs -...., 9968'- 11114' Top(MD) Btm(MD) Top(TVD) Btm(TVD) Detail . • 7,105' 8,511' 5,484' 6,513' Squeezed i Some squeezed & all isolated 7 „ + 9,968' 11,114' 7,707 8,807' by BP at 9,950' KB • 1159 "2 . r +1 5,492' 5,538' 4,386' 4,414' Open PBTD = 5553' TD = 11600' MAX HOLE ANGLE = 54.5 @ 5600' MD Revised By: JLL 01 -17 -2013 • • Cook Inlet Basin Proposed Well No: Ba -27 Ililcarp Alaska, LLC Last Completed: 2 -10 -1993 RKB: MSL = 101' ADL: 17595 PTD: 183 -116 API: 50- 733 - 20368 -00 Mudline= 203' Water Depth= 102' Leg 2, Slot 5 MGS St 17595 27 a Casing Detail 32" Size Type Wt/ Grade/ Conn ID Top Btm Cement CMT Top Sacks 'f 32" Structural Surf 185 MS ' 's 13 -3/8" Surface 54.5/68/61 #, 12.415 Surf 3,407' 2,500+ Surf Top K55/N80, BTC 560 Job 53.5, 595, BTC 8.535 Surf 309' • t 40, 595, BTC 8.835 309' 3,547' ' 9 -5/8" Intermediate 43.5, 595, BTC 8.755 3,547' 4,995' 1,400 6,470 CBL 47, 595, BTC 8.681 4,995' 6,659' - f 53.5, 595, BTC 8.535 6,659' 8,843' 7" Liner 29, HC95, BTC 6.184 8,590' 11,266' 925 ' 35, S95, BTC 6.004 11,266' 11,592' 13-3/8 ' b 3407 rtorations 617'- 3,636' Tubing Detail a ertorations SRZ ,782 " - 3,600' Size Type Wt /Grade /Conn ID Top Btm s . , r ertorations CIBP 4,95' H OC 4925 ' I - • • , ,017' - 4,048' 3 -1/2" Prod Tubing 9.2, N80, TDS w/ Special CI Cplgs 2.992 31' 3,967' LS: Tag cement 1 at 5,553'. Tubing C aak TOC in 93/8' punches 5,035' ♦ nuuwa ®5,222' - 5,040'.8/14/05 _ Jewelry Detail Tubing punches CIBP in SS ®5,313' for 2nd stage # Depth Length ID Item cement plug at 6,149' - 8,155'. SS: Tag cement at 5,338'. Tubing a 300' SSSV Perfoations punches 4,839' - 5,492 - 5,538' ♦ 4,841'. (8/18/05) b 3,567' Completion Packer TOC CBL ' 8470' , c 4,950' CIBP A .2 'I- # ' , Long String 3 2 7,014' 2.42 Crossover, 3 -1/2" EUE x 3 -1/2" 3 7,017' 22.63 KOBE 3" B cavity LI a, 4 7,039' 1.72 Crossover, 3 -1/2" Butt x 3 -1/2" EUE 5 ' _ 6' • 5 7,041' 9.4 2.992 Pup joint 3 -1/2" TDS tubing Oil Top G &G 7100 6 7,051' 0.76 WREG r. Sgzd Perfs Short String , , 7105" 8511' A 5,313' CIBP e-•- B 7,006' 0.74 Crossover, 3 -1/2" TDS x 2 -3/8" EUE TOL ( 8590' C 7,006' 10.07 Pup Joint 2 -3/8" 4.6# N80 tubing 9- 5/8 " History Y - BP@ 9950' 2010 - Well skipped during well circulation work since records show 9.8 ppg brine circ in 2005 and no pressure on tubing or annulus 2005 - Bundle test of LS, SS, and annulus to 1500 psi for 30 min (AOGCC witness) - good. Open Perfs Perforations 9988'- 11114' � Top(MD) Btm(MD) Top(TVD) Btm(TVD) Detail � ► 7,105' 8,511' 5,484' 6,513' Squeezed NIF 7° 9,968 11,114 7,707 g 807 Some squeezed & all isolated 11592' . ' ° by BP at 9,950' KB PBTD = 5553' TD = 11600' 5,492' 5,538' 4,386' 4,414' Isolated w/ CIBP MAX HOLE ANGLE = 54.5 @ 5600' MD 4,017' 4,048' 3,372' 3,394' Open 3,782' 3,800' 3,208' 3,220 Future 3,617' 3,636' 3,094' 3,107' Future Revised By: JLL 01 -17 -2013 • • HILCORP - Baker Reactivation 2012 Baker Platform Operation and Development Plan Cook Inlet, AK BAKER REACTIVATION OPERATION AND DEVELOPMENT PLAN Owner: Hilcorp Alaska, LLC Location: Baker Platform Cook Inlet, Alaska PROJECT OVERVIEW Hilcorp Alaska, LLC is in the planning stages for re- activation of the Baker Platform. Project planning and execution will be conducted in a phased approach. This document outlines the operation and development plan for Phase I of the Baker Reactivation project. The planned development of phase I is to bring up to three existing gas wells online, condition the gas for sales, and supply sales gas to a third party Cook Inlet Producer via existing subsea pipeline. Any produced fluids during phase I will be injected down hole via the existing permitted disposal well (Well Ba -17). Attached is a proposed flow schematic for the surface process equipment if the wells are deemed to be productive. WELL INFORMATION & WELL SAFETY SYSTEMS Phase I of the Baker reactivation project targets well testing and reactivation of up to three existing wells (2ea current gas wells Ba -14 & 18 — lea converted abandoned water injection wells Ba 27). Each well safety system will be inspected, and properly tested in accordance with State regulations Title 20 AAC 25.265. PROCESS OVERVIEW Well flow lines will be piped above deck from the existing well rooms to new process equipment housed in modular structures located on the drill deck proper. The new process equipment will consist of the following: • Group and Test Separator Package • Dehydration Package • Produced Water Injection Pump(s) Under normal operating conditions, the gas well(s) will be routed through the gross separator. If more than one gas well is on production, individual well testing will be routed through the test separator as required for optimal performance and in accordance with state regulation. The gas stream(s) will be co- mingled after separation and routed through the dehydration package. Gas quality from the dehydration package will be routed through an existing custody transfer meter (meter #1101) then to the subsea pipeline tie -in. Fuel gas for platform utilities will be taken off the processed production gas downstream of the dehydration package. In the event the well production is shut in, fuel gas service can be maintained by flowing gas from shore through the sales pipeline. All fuel gas will be metered. The Baker platform is equipped with two existing temporary permitted disposal wells (Ba -17 & Ba -16). The group and test separators will be tied in to a produced water tank feeding two new Baker Reactivation - 1 - September 7, 2012 • • HILCORP - Baker Reactivation 2012 Baker Platform Operation and Development Plan Cook Inlet, AK injection pumps that will take the produced fluids from the vessels and inject it down the Ba -17 disposal well. Produced fluids disposal will be metered as currently required. The Baker platform is equipped with an existing flare system that is inactive. The flare and flare scrubber vessel will disconnected from the existing flare system and re -used as a knock out drum and vent stack. PSV's from the separator and dehy packages will be connected to a new vent header routed to the knock out drum and out the vent stack (existing flare). A new blow down valve will be installed and piped to the vent header to blow down the gas train to facilitate safe operations and maintenance. PROCESS SAFETY SYSTEMS & MONITORING The Baker platform is currently operating in an unmanned "Lighthouse" mode. Hilcorp maintains and actively monitors the existing SCADA system keeping "Lighthouse" mode generation online, cathodic protection (CP) sleds energized, navigation and heli -deck lights energized, etc. The SCADA system communicates to a land based monitoring station via microwave radio. The new process safety system controls, instrumentation, and well safety systems will be tied into the existing SCADA network. For Phase I operation the new process system will be monitored and controlled remotely similar to how remote land based gas pads are currently operated through -out Cook Inlet. The new process safety system will be configured to enable the following remote control and monitoring functions: • Emergency Shutdown w /Process Blowdown (ESD) • Individual Well Shutdown (WSD) • Process Shutdown (PSD) • Process Start-up (Only from PSD Condition, ESD requires Manual Reset for Re -start) • Sales Gas Flow Control • 24 HR Monitoring of Process Conditions, Alarms, and Shutdowns Hilcorp will monitor process conditions 24 hours per day from their manned facility at Swanson River. All process alarms will be logged, annunciated and acknowledged via the designated lead operator on call. The system will be designed for remote operation allowing the operator the ability to start and stop process operations once the safety system has been armed and no ESD alarm condition becomes active. Re- starting the process remotely will only be allowed from a PSD process state. If an ESD alarm condition becomes active and the process safety system closes in the wells (via the well safety system) Hilcorp Operations will be required to travel to the platform to verify the alarm conditions have been corrected and manually reset well controls before the process system can be brought back online. Well Safety Description Baker Reactivation - 2 - September 7, 2012 HILCORP - Baker Reactivation 2 12 • Baker Platform Operation and Development Plan Cook Inlet, AK A surface safety valve is installed on the production well(s), automated to close on high pressure, low pressure, or external process and emergency shutdowns. A surface controlled subsurface safety valve is currently installed on well BA -14, automated to close on emergency shutdowns. Any work that involves the pulling of tubing and recompletion of a well will include the installation of a surface controlled subsurface safety valve. • Process Safety Description Process protections include pressure safety valves on the vessels to prevent overpressure of the system. In the event of a process upset — high pressure, low pressure, high level in the produced water system, gas detection — the well head surface safety valves and the pipeline shutdown valves will automatically close. This isolates the process from the wells and the pipeline until the process upset can be determined and cleared. In an emergency shutdown condition — triggered by fire — the process system will be shutdown as described above. Additionally the well subsurface safety valves will close and the process system from the surface safety valves to the pipeline shutdown valve will be relieved of pressure (blown down) through an automated blow down valve. The gas will flow out of the system through a flare scrubber and vent out the old flare boom well away from the platform decks. Fire and Gas Safety System Fire and gas detection will be provided in the well rooms and new process modules. Fire and gas alarms will be monitored remotely 24 hours a day from Swanson River via the SCADA network. Operators on call will receive alarm notification through the Wonderware HMI and via personal pager /cell phone. Operators will have the ability to manually initiate a PSD or ESD remotely depending on the circumstance. Upon detection of a confirmed fire event a facility ESD will be initiated automatically - shutting down and isolating the process, shutting in the wells (SSV & SSSV), and blowing down the system. Upon detection of combustible gas at 20% LEL (Low Gas Alarm) operators will receive an alarm notification of the event. If the situation escalates and detection of combustible gas at 40% LEL (High Gas Alarm) occurs the fire and gas system will initiate a facility ESD automatically. Each well safety valve system will be equipped with a fusible plug in series with the surface and subsurface safety valves signal lines. In the event of a fire in a well room, the fusible plugs will melt releasing signal line pressure holding the safety valves open. The surface and subsurface safety valves will return to their failsafe state of closed and the wells will immediately shut -in. Baker Reactivation - 3 - September 7, 2012 • • I I ! i 1 Z I Y IP II Rid 0? . Eillit al CO 1:: m R - r ( I I I' CD 9.0 , '11 - o7 1311111111111111 momwl � 1 03-2 § � N! s U � y L a ' p • d� 4 ! A A s wO S 3 wi W Li i.s74_, Lz i.,v4_, q _)-4 41:114 �I 3S I 7130.1. 1131 M .., 4 1..: r na+n .noN • II • 31 • 0 II ig Q • Q� ; 0 l i 0 1 0\ 6 s Z p 1 " " = 0 ; U Rey 14 • I. = 0 • = 0 ff j f) 6 g 1 g ! • Schwartz, Guy L (DOA) From: Ted Kramer <tkramer @hilcorp.com> Sent: Saturday, March 02, 2013 9:12 AM To: Schwartz, Guy L (DOA) r �� Cc: Robert Kendrick - (C) /^ Subject: Baker Platform Well # 27 Sundry 313 -024 `' 11 \ v& Guy, Thanks for taking the time to talk to Bob Kendrick and myself on Friday March 1, 2013 about the above well. As per our conversation We would like to do the following regarding the well Sundry: 1. Withdraw the current application for Sundry #313 -024 in favor of the new application sent over via courier with the following additions: a. Conduct an MITOA on the 9 -5/8" X 13 -3/8" annulus to 400 psi. (See detail in the discussion below). Should the well fail the MITOA, then a PIR will be established and mitigation steps explored. Discussion Research of the 13 -3/8" casing shoe test on the Ba 27 revealed that a test was done on 10 -1 -83 to an equivalent mud wt of 13.2 ppg. The mud wt in the hole when the 9 -5/8 casing was cemented on 12/03/83 was 10.3 ppg. Therefore the maximum surface pressure for the MITOA test should be (13.2- 10.3) *.052 *2946 = 444 psi so we do not exceed the original shoe test pressure. Research of the bleed history of the Ba -27 revealed no indication that the well has built up pressure and been in any sort of a periodic bleed down program. Thanks again for your time. It helps to have a face to face dialogue when discussing less conventional means of working on wells. I know I appreciate it and Bob does as well. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907 - 777 -8420 C 985 - 867 -0665 1 • • Q -//7 Davies, Stephen F (DOA) �� -31 — From: Davies, Stephen F (DOA) Sent: Monday, September 24, 2012 3:01 PM To: 'David Buthman Cc: Schwartz, Guy L (DOA) Subject: RE: MGS ST 17595 -27 (PTD 183 -116) Dave, Thank you. A spacing exception will not be required for the proposed testing of the Tyonek 40 series sandstones in the Baker -27 well. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907 -793 -1224 WOOD WO _ ��` Fax: 907 - 276 -7542 Regards, From: David Buthman [mailto:dbuthman@@hilcorp.com] Sent: Monday, September 24, 2012 9:11 AM To: Davies, Stephen F (DOA) Cc: Chris Kanyer Subject: MGS ST 17595 -27 (PTD 183 -116) Hi Steve, Per our discussions this morning regarding the Baker -18 well: The Baker -18 well is not capable of gas production from the Tyonek 40 series sandstones. A plug was set in the tubing at 4790' in 1997, which together with the packer at 3966', renders the Tyonek 40 series sandstones not capable of production in the wellbore. In addition, the Baker -32 well is also no longer capable of production from the Tyonek 40 series sandstones, due to a plug with cement at 7226' set in 2005. Because neither the Baker -18 nor the Baker -32 are capable of production from the Tyonek 40 series sandstones, the proposed testing of the Tyonek 40 series sandstones in the Baker -27 well should not require a spacing exemption. Please advise. Rgds, David B. Buthman Senior Geologist Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 1 ' • • m op TA �).-,,,�,, - s , , THE STATE Alaska Oil and Gas , - _ fALAS� Conservation Commission iii _ GOVE RNOR SEAN PARNELL O� _t *,,, � 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALA Main: 907.279.1433 Fax: 907.276.7542 Chad Helgeson Operations Engineer Hilcorp Alaska, LLC i 3 - ( 1 3800 Centerpoint Drive, Suite 100 1 Anchorage, AK 99503 Re: Middle Ground Shoal Field, Undefined Gas Pool, MGS ST 17595 -27 Sundry Number: 312 -352 Dear Mr. Helgeson: ':.,s, # ...Id,.;: ; v ';_ 'i;,i 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. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to test or produce is contingent upon issuance of a conservation order approving a spacing exception. Hilcorp Alaska, LLC assumes the liability of any protest to the spacing exception that may occur. 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, - )).e.,,(.. , ) - 74-L____. , f //) Cathy 1 Foerster Chair DATED this D day of September, 2012. Encl. , . • `/ a IV STATE OF ALASKA ` O � � S E F 1 12.01"z ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool el . Repair Well ❑ Change Approved Program 0 Suspend ❑ Plug Perforations ❑ Perforate 151 • Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Test P1 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Development ❑ Exploratory ❑ 183 -116 3. Address: Stratigraphic ❑ Service 6. API Number: 3800 Centerpoint Drive, Suite 100, Anchorage, AK 99503 50- 733 - 20368 -00 • 7. If perforating, closest approach in pool(s) opened by this peration to nearest 8. Well Name and Number. property line where ownership or landownership chan s: ' ( 4. 1'2. MGS ST 17595 (Baker) 27 Spacing Exception Required? Yes / No Se:, 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0017595 • Middle Ground Shoal Field / A Oil, B C and D Oil, E F and G 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): 11,600 t 9,257 • 5,553 Cement Plug: SS 5,336' - LS 5,553' N/A Casing Length Size MD TVD Burst Collapse Structural 185' 32" 185' 185' Conductor Surface 3,407 13 -3/8" 3,407' 2,952' 2,730 psi 1,130 psi Intermediate Production 8,843' 9 -5/8" 8,843' 6,763' 6,820 psi 4,230 psi Liner 3,022' 7" 11,592' 9,250' 9,690 psi 7,820 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3 -1/2" dual N -80 SS 7,005' - LS 7,051' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Description Summary of Proposal (g 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Q _ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 9/18/2012 Commencing Operations: Oil ❑ Gas © • WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson 777 -8405 (Direct) Printed Name Chad Helgeson 777 -8300 Title Operations Engineer Signature 7 ' � ^'� �O Phone Date v COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: /.2 _3sd_ Plug Integrity ❑, BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ q r Other. , ' 0r r O v a, i e cl • f r G Z �° 1 O fin. rill 1 I �v' j. i f ci t't C Subsequent Form Required: APPROVED BY /� / Approved by: / ' y L O� COMMISSIONER THE COMMISSION Date: 9 - 2� / . //''��,,��v t 1/ � / _ G am/ f ICdOSi�ri�e �i ' f � 1 � S i n DuP a r �1/ 1� ORIGINAL. , ,, • • Well Prognosis Well: MGS ST 17595 -27 Hilcorp Alaska, LLC Date: 9/11/2012 Well Name: MGS ST 17595 -27 (Ba -27) API Number: 50- 733 - 20368 -00 Current Status: Plugged Wlnj Leg: 2 Estimated Start Date: September 18, 2012 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 183 -116 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Chris Kanyer (907) 777 -8377 (0) AFE Number: 1222507 Current Bottom Hole Pressure: N/A (Well plugged and pressure tested to 1500 psi) Maximum Expected BHP: — 1,933 psi @ 4,295' TVD (Using max .45 psi /ft gradient for new T -40 perfs) Max. Allowable Surface Pressure: —1,744 psi (Based on 0.044 psi /ft gas gradient) Brief Well Summary This well was drilled and completed as an oil well in the Tyonek F & Hemlock in 1983 -1984. Subsequent workovers were performed in 1984 to stimulate the reservoir through reperfs, acidizing, and fracing these intervals. The workover in 1987 installed a hydraulic lift completion and added the Tyonek B, C, & D sands. The well was again worked over in 1991 to isolate the Tyonek F and Hemlock sands. A workover in 1993 raised the completion and added the Tyonek A perfs. In 2000 a variance to convert well to water injection was approved. Water injection was then halted in 2002. A thru- tubing abandonment of all open Tyonek oil sands was performed in 2005 and the well and isolation cement was pressure tested to 1500psi at that time. The current recompletion plan is to patch & pressure test long string tubing, perforate and test the T -40 sand with temporary well test equipment. Depending on the results of the initial perforating the_ contingency work plan, includesplug ing back the T-40 or adding perforations of the T 40A sand, and again flow test the well. If successful, modularized gas conditioning facilities will be installed (see the attached diagram and description of new production equipment). New processing equipment and facilities will be used for long term flow. Notes Regarding Wellbore Condition • Well current well status is a plugged water injector /service well. o See attached existing wellbore schematic for cement tag depths, etc. Brief Procedure: 1. Mob slickline, e-line, test equipment to the Baker Platform. 2. RU slickline. Pressure test lubricator 250psi low /2500psi high. 3. Perform charted pressure test on casing & both strings of tubing (jug test) to 1,500psi for 30 min. 4. RIH w/ 2.812 - 2.867 "gauge ring in the long string (LS) and tag cement at +/- 5,553'. 5. RD slickline. 6. Install and test SSV, RU temporary flowback /test equipment and vent stack. 7. RU Eline. --''! C L i.,_ 1- 5 -h, ye-rij� TOG (G4.4* P -) 8. RIH with permanent patch in LS and patch tubing punch from +/- 5,035' to +/- 5,040'. 9. Perform charted pressure test of LS to 1,500psi for 30 min. 10. BD ELine. • • Well Prognosis Well: MGS ST 17595 -27 Hilcorn Alaska, LLC Date: 9/11/2012 11. RU Slickline, swab well to +/- 1500', RD slickline. 12. RU Eline. 13. RIH on LS and perforate T -40 from_ + 5 492' to +j-5,538' w/ deep penetrating charges. 14. RD Eline. 15. Flow test well and vent gas to atmosphere. (If capable AOF well test will be completed). Contingency (pending flow test results): a. [If water production from T -40] i. RIH LS and set plug at +/- 5,485'. ii. RIH LS and dump bail +/ -25' of cement on bridge plug. iii. RIH LS and perforate T -40A from +/- 5,371' to +/- 5,410'. / p 5 , 3 iv. Flow test well. b. [If limited ( <500Mcfd) production from T -40] i. RIH LS and perforate T -40A from +/- 5,371' to +/- 5,410'. ii. Flow test well. 16. Shut in well. 17. Pending successful flow test(s), install modularized gas conditioning facilities (see attached). 18. Turn well over to production. Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. Modularized gas conditioning facilities diagram (pending successful well testing) . • 14 • • Cook Inlet Basin SCHEMATIC Well No: Ba -27 Hilcorp Alaska, LLC Last Completed: 2 -10 -1993 RKB: MSL =101' ADL: 17595 PTD: 183 -116 API: 50- 733 - 20368 -00 Mudline 203' Water Depth= 102' Leg 2, Slot 5 MGS St 17595 27 1 E.--1 KB: MSL k Mean Sea Level Mud Line Casing Detail ,, ` Cement Size Type Wt/ Grade/ Conn ID Top Btm Sacks CMT Top 32" ' 32" Structural Surf 185 MS 13 -3/8" Surface 54.5/68/61 #, 12.415 Surf 3 407 2,500+ Surf Top K55 /N80,BTC 560 Job 53.5, 595, BTC 8.535 Surf 309' 40, 595, BTC 8.835 309' 3,547' 9 -5/8" Intermediate 43.5, S95, BTC 8.755 3,547' 4,995' 1,400 6,470 CBL 47, S95, BTC 8.681 4,995' 6,659' I 53.5, S95, BTC 8.535 6,659' 8,843' 7" Liner 29, HC95, BTC 6.184 8,590' 11,266' 925 • 98 35, S95, BTC 6.004 11,266' 11,592' A /1 r ine br Short String 13 - 318" Size Type Wt /Grade /Conn ID Top Btm 3407' 3 -1/2" Prod Tubing 9.2, N80, TDS w/ Special CI Cplgs 2.992 31' 7,005' 4 11/7 7 , 4') - Long String LS: Tag cement r4 at 5,553'. Tubing '12,03 Size Type Wt /Grade /Conn ID Top Btm punches 5 - 5,1740'.8/14/05 calcTOC�n 3 -1/2" Prod Tubing 9.2, N80, TDS w/ Special CI Cplgs 2.992 31' 7,051' Tubing Dui - 9518' annulus for 2nd stage = = @5,222'. Jewelry Detail cement pug at 6,149' - 6,155'. # Depth Length ID Item itq cement N t w 7u• at 5,336 Tubing 17(145 Long String OGrn6h f- J I punches 4,839' _ - - -.� I r- � 4,841'.(8116405) �5rf . i D 1 31' 2.992 Dual 11" CIW -DCB Hanger, 3" Type "H" TOCCBL 5-M', BPV profile, 3 -1/2" Butt Dwn 6470' i �r- - A if 2 2 7,014' 2.42 Crossover, 3 -1/2" EUE x 3 -1/2" �j7 n, 2 1 3 7,017' 22.63 KOBE 3" B cavity 3 r a,_iau,, . 4 4 7,039' 1.72 Crossover, 3 -1/2" Butt x 3 -1/2" EUE • �---� 5 7,041' 9.4 2.992 Pup joint 3 -1/2" TDS tubing 1 4 6 7,051' 0.76 WREG 5 6 Short String 01 Topcsc , 7100' A 7,006' 0.74 Crossover, 3 -1/2" TDS x 2 -3/8" EUE sgzdPerfs B 7,006' 10.07 Pup Joint 2 -3/8" 4.6# N80 tubing y .. 7105' - 8511' History 2010- Well skipped during well circulation work since records show 9.8 ppg brine circ in • *-� 2005 and no pressure on tubing or annulus TOL 88590 y 2005 - Bundle test of LS, SS, and annulus to 1500 psi for 30 min (AOGCC witness) - good. 9- 518 "Z • • . ' ' Perforations 8844 Top(MD) Btm(MD) Top(TVD) Btm(TVD) Detail BPg 9950' 7,105' 8,511' 5,484' 6,513' Squeezed , ' 9,968' 11,114' 7,707' g 807' Some squeezed & all isolated by BP at 9950' KB Open Perlis 40,:i 9968' - 11114' 0 11592 } t '.:70: j? y PBTD = • 5553' TD = 11600' MAX HOLE ANGLE = 54,5 @ 5600' MD Revised By: DMA 9 - - 2012 • • 14 • Cook Inlet Basin PROPOSED Well No: Ba -27 Hilcer' Alaska, LLC Last Completed: 2 -10 -1993 RKB: MSL = 101' ADL: 17595 PTD: 183 -116 API: 50- 733 - 20368 -00 Mudline= 203' Water Depth= Leg 2, Slot 5 MGS St 17595 27 61 1 l . Me SL Mean Sea Level Mud Line Casing Detail a Size Type Wt/ Grade/ Conn ID Top Btm Cement Sacks CMT Top 32" ' 32" Structural Surf 185 MS 13 -3/8" Surface 54.5/68/61 #, 12.415 Surf 3,407' 2,500+ Surf Top K55/N80, BTC 560 Job 53.5, 595, BTC 8.535 Surf 309' 40, S95, BTC 8.835 309' 3,547' 9 -5/8" Intermediate 43.5, 595, BTC 8.755 3,547' 4,995' 1,400 6,470 CBL 7 47, 595, BTC 8.681 4,995' 6,659' • 53.5, S95, BTC 8.535 6,659' 8,843' 29, HC95, BTC 6.184 8,590' 11,266' 9 7" Liner 35, S95, BTC 6.004 11,266' 11,592' 925 i Short String 13 -3/8" Size Type Wt /Grade /Conn ID Top Btm 3407' 3 -1/2" Prod Tubing 9.2, N80, TDS w/ Special CI Cplgs 2.992 31' 7,005' LS: Tag cement Long String at 5,553'. Tubing I n ,..._.. 1 Size Type Wt /Grade /Conn ID Top Btm punches 5,035' - 5,040'. 8/14/05 Cale TOC in Tubing punches J_ 9-518" annulus 3 -1/2" Prod Tubing 9.2, N80, TDS w/ Special CI Cplgs 2.992 31' 7,051' tor 2nd stage _ - @ 5,222'. cement plug at -- Jewelry Detail 6,149' - 6,155. SS. Tag cement # Depth Length ID Item at 5,336'. Tubing N punches 4,839' - Long String 4,841'. (8/16/05) Perfoa5ons -÷ 1 31' 2 992 Dual 11" CIW -DCB Hanger, 3" Type "H" TOCCs47a BL :a1 BPV profile, 3 -1/2" Butt Dwn _ A 2 7,014' 2.42 Crossover, 3 -1/2" EUE x 3 -1/2" 2 = '11.8 3 I , . „ „ I 3 7,017' 22.63 KOBE 3" B cavity rte: 4 7,039' 1.72 Crossover, 3 -1/2" Butt x 3 -1/2" EUE ' - " 5 7,041' 9.4 2.992 Pup joint 3 -1/2" TDS tubing - d'. ©5 6 7,051' 0.76 WREG Oil Top GBC Short String 7100 . A 7,006' 0.74 Crossover, 3 -1/2" TDS x 2 -3/8" EUE - 1 . , ...,,... Sqzd Perfs ,; 7105- 8511' B 7,006' 10.07 Pup Joint 2 -3/8" 4.6# N80 tubing ' "` History . . . +-- 2010- Well skipped during well circulation work since records show 9.8 ppg brine circ in TOL @also 2005 and no pressure on tubing or annulus .0 154, 2005 - Bundle test of LS, SS, and annulus to 1500 psi for 30 min (AOGCC witness) - good. 9-5/8"Z • 8844' Perforations sP @99 Top(MD) Btm(MD) Top(TVD) Btm(TVD) Detail 7,105' 8,511' 5,484' 6,513' Squeezed 9,968' 11,114' 7,707' g 807' Some squeezed &all isolated 1 by BP at 9,950' KB Open Perfs ' 9968'- 11114' ±5,492' ±5,538' ±5,386' ±5,431' New Perforations • `A 7 " 11592' , , ' PBTD = 5553' TD = 11600' MAX HOLE ANGLE = 54.5 @ 5600' MD Revised By: DMA 9 -7 -2012 • • HILCORP - Baker Reactivation 2012 Baker Platform Operation and Development Plan Cook Inlet, AK BAKER REACTIVATION OPERATION AND DEVELOPMENT PLAN Owner: Hilcorp Alaska, LLC Location: Baker Platform Cook Inlet, Alaska PROJECT OVERVIEW Hilcorp Alaska, LLC is in the planning stages for re- activation of the Baker Platform. Project planning and execution will be conducted in a phased approach. This document outlines the operation and development plan for Phase I of the Baker Reactivation project. The planned development of phase I is to bring up to three existing gas wells online, condition the gas for sales, and supply_sales gas to a third party Cook Inlet Producer via existing subsea pipeline. Any produced fluids during phase I will be injected down hole via the existing permitted disposal well (Well Ba -17). Attached is a proposed flow schematic for the surface process equipment if the wells are deemed to be productive. WELL INFORMATION & WELL SAFETY SYSTEMS Phase I of the Baker reactivation project targets well testing and reactivation of up to three existing wells (2ea current gas wells Ba -14 & 18 — lea converted abandoned water injection wells Ba 27). Each well safety system will be inspected, and properly tested in accordance with State regulations Title 20 AAC 25.265. PROCESS OVERVIEW Well flow lines will be piped above deck from the existing well rooms to new process equipment housed in modular structures located on the drill deck proper. The new process equipment will consist of the following: • Group and Test Separator Package • Dehydration Package • Produced Water Injection Pump(s) Under normal operating conditions, the gas well(s) will be routed through the gross separator. If more than one gas well is on production, individual well testing will be routed through the test separator as required for optimal performance and in accordance with state regulation. The gas stream(s) will be co- mingled after separation and routed through the dehydration package. Gas quality from the dehydration package will be routed through an existing custody transfer meter (meter #1101) then to the subsea pipeline tie -in. Fuel gas for platform utilities will be taken off the processed production gas downstream of the dehydration package. In the event the well production is shut in, fuel gas service can be maintained by flowing gas from shore through the sales pipeline. All fuel gas will be metered. The Baker platform is equipped with two existing temporary permitted disposal wells (Ba -17 & Ba -16). The group and test separators will be tied in to a produced water tank feeding two new Baker Reactivation - 1 - September 7, 2012 • • HILCORP - Baker Reactivation 2012 Baker Platform Operation and Development Plan Cook Inlet, AK injection pumps that will take the produced fluids from the vessels and inject it down the Ba -17 disposal well. Produced fluids disposal will be metered as currently required. The Baker platform is equipped with an existing flare system that is inactive. The flare and flare scrubber vessel will disconnected from the existing flare system and re -used as a knock out drum and vent stack. PSV's from the separator and dehy packages will be connected to a new vent header routed to the knock out drum and out the vent stack (existing flare). A new blow down valve will be installed and piped to the vent header to blow down the gas train to facilitate safe operations and maintenance. PROCESS SAFETY SYSTEMS & MONITORING The Baker platform is currently operating in an unmanned "Lighthouse" mode. Hilcorp maintains and actively monitors the existing SCADA system keeping "Lighthouse" mode generation online, cathodic protection (CP) sleds energized, navigation and heli -deck lights energized, etc. The SCADA system communicates to a land based monitoring station via microwave radio. The new process safety system controls, instrumentation, and well safety systems will be tied into the existing SCADA network. For Phase I operation the new process system will be monitored and controlled remotely similar to how remote land based gas pads are currently operated through -out Cook Inlet. The new process safety system will be configured to enable the following remote control and monitoring functions: • Emergency Shutdown w /Process Blowdown (ESD) • Individual Well Shutdown (WSD) • Process Shutdown (PSD) • Process Start-up (Only from PSD Condition, ESD requires Manual Reset for Re -start) • Sales Gas Flow Control • 24 HR Monitoring of Process Conditions, Alarms, and Shutdowns Hilcorp will monitor process conditions 24 hours per day from their manned facility at Swanson ,River. All process alarms will be logged, annunciated and acknowledged via the designated lead operator on call. The system will be designed for remote operation allowing the operator the ability to start and stop process operations once the safety system has been armed and no ESD alarm condition becomes active. Re- starting the process remotely will only be allowed from a PSD process state. If an ESD alarm condition becomes active and the process safety system closes in the wells (via the well safety system) Hilcorp Operations will be required to travel to the platform to verify the alarm conditions have been corrected and manually reset well controls before the process system can be brought back online. Well Safety Description Baker Reactivation - 2 - September 7, 2012 • HILCORP - Baker Reactivation 2012 Baker Platform Operation and Development Plan Cook Inlet, AK A surface safety valve is installed on the production well(s), automated to close on high pressure, low pressure, or external_rocess and emergency shutdowns. A surface controlled subsurface safety valve is currently installed on well BA -14, automated to close on emergency shutdowns. Any work that involves the pulling of tubing and recompletion of a well will include the installation of a surface controlled subsurface safety valve. Process Safety Description Process protections include pressure safety valves on the vessels to prevent overpressure of the system. In the event of a process upset — high pressure, low pressure, high level in the produced water system, gas detection — the well head surface safety valves and the pipeline shutdown valves will automatically close. This isolates the process from the wells and the pipeline until the process upset can be determined and cleared. In an emergency shutdown condition — triggered by fire — the process system will be shutdown as described above. Additionally the well subsurface safety valves will close and the process system from the surface safety valves to the pipeline shutdown valve will be relieved of pressure (blown down) through an automated blow down valve. The gas will flow out of the system through a flare scrubber and vent out the old flare boom well away from the platform decks. Fire and Gas Safety System Fire and gas detection will be provided in the well rooms and new process modules. Fire and gas alarms will be monitored remotely 24 hours a day from Swanson River via the SCADA network. Operators on call will receive alarm notification through the Wonderware HMI and via personal pager /cell phone. Operators will have the ability to manually initiate a PSD or ESD remotely depending on the circumstance. Upon detection of a confirmed fire event a facility ESD will be initiated automatically - shutting down and isolating the process, shutting in the wells (SSV & SSSV), and blowing down the system. Upon detection of combustible gas at 20% LEL (Low Gas Alarm) operators will receive an alarm notification of the event. If the situation escalates and detection of combustible gas at 40% LEL (High Gas Alarm) occurs the fire and gas system will initiate a facility ESD automatically. Each well safety valve system will be equipped with a fusible plug in series with the surface and subsurface safety valves signal lines. In the event of a fire in a well room, the fusible plugs will melt releasing signal line pressure holding the safety valves open. The surface and subsurface safety valves will return to their failsafe state of closed and the wells will immediately shut -in. II Baker Reactivation - 3 - September 7, 2012 e 1• BO o H t USE (E) RARE V- 0310 .......................... �N �0 gj C LL ] 0 • /■ ® HI V -001 5 000A I# • �— ' rn - \ / = e SEf • /N4 / ® ,350 55S, I •.--- 114 1i 1 SET e z ET WELL 14 ^ 58V LL e 0 / / \ N 2zo 78 — LL teo 50 ar o • _ LL 350 r; 9 ® V -003 rn Fe • ® I� rn II • GLYCOL REGEN WELL 18 0 Tao �B SE NI a k., 3A SE ]50 5000/ • — HI V -002 II ae • —II— WELL 27 5000% NISI T • — 001 Z.-0 i n-II P V -001 V -002 a (E) V -0310 T -001 WATER INJECTION SEPARATOR, GROUP SEPARATOR, TEST TEC DEHYDRATION FLARE SCRUBBER PRODUCED LIQUIDS 11 GPM, 800 PSIG DISCH. MAWP = 1480 PSIG • 100'F MAWP = 1480 PSIG 0 100'F MAWP = 1350 PSIG 0 200'F MAWP = 125 PSIG • 100'F MAWP = ATMOSPHERIC WELL 17 DWG. NUMBER 5111 REFERENCE DRAWINGS NOTES• REV DATE REVISED ' Y UV o�m.mn,.e ...wv�. can.n�c v. �a BAKER PLATFORM IN OFA A OW06/11 ISSUED FOR Rene/ NB WV WV ' sv w APPR?""ri COOK INLET ALASKA WV M6 �ilY 0 111 •. 4B1n * . ,..m w L BAKER REACTIVATION — PHASE 1 HILCORP APPROVAL �w� . = � PROCESS FLOW DIAGRAM M RR_+` AS NOIEO DRAWING NO. SIT N0. REV NQ I,A,< 9 /2012 ,1o;3-U27 $ HILCORPALASKA,LLC FD_001 001 A • • TRANSMITTAL LETTER CHECKLIST � j , WELL NAME / � 7S / PTD# /l6 Development V Service Exploratory Stratigraphic Test Non - Conventional Well /r FIELD: Raffe:Yc�i LcC ` POOL: /:64 Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - . API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject tr, fiill compliance with 20 AAC EXCEPTION 25.055. Approval to -3 4 1" " contingent upon issuance of a y y vir ervation o der appr• .: a spacing exception. - // 4.54 4 L (' assumes the lia o any protest tab the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 9/09/2011 vC _i 7 • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Friday, September 14, 2012 8:36 AM To: 'Chris Kanyer' Cc: 'Chad Helgeson'; 'David Buthman'; Schwartz, Guy L (DOA) Subject: RE: Sundry: MGS ST 17595 -27 (PTD 183 -116) Chris, As I understand it, Baker 27 will require a spacing exception because the T -40 sand is open to another well within 3000'. The spacing exception application process is presented in 20 AAC 25.055(d), and it usually requires 6 to 7 weeks (including a mandatory 30 -day public comment period). The application must also present a brief explanation as to why the operator has chosen to drill the specified location, rather than a location that conforms to the spacing requirements. Regards, Steve Davies AOGCC From: Davies, Stephen F (DOA) Sent: Thursday, September 13, 2012 11:27 AM To: 'Chris Kanyer' Cc: Chad Helgeson; David Buthman; Schwartz, Guy L (DOA) Subject: RE: Sundry: MGS ST 17595 -27 (PTD 183 -116) Chris, Please submit the sundry application for abandoning all open perforations below the T -31 in Baker 18 as soon as you can. For Baker 27, a spacing exception will not be needed unless Hilcorp perforates a reservoir sand that is: 1) open to another well in the same governmental section, 2) open to another well within 3000', or 3) open within 1500' of a property line. Thanks, Steve Davies AOGCC 907 - 793 -1224 Thanks, From: Chris Kanyer [mailto:ckanyerc hilcorp.com] Sent: Thursday, September 13, 2012 11:15 AM To: Davies, Stephen F (DOA) Cc: Chad Helgeson; David Buthman Subject: RE: Sundry: MGS ST 17595 -27 (PTD 183 -116) 1 After further review of well Ba-18, ther e is a plug in the tubing at 4790' (set in Jan 1997) that isolating the T -40A from production (see attached schematic). In the future, a sundry will be submitted to abandon all open perforations below the T -31 in this well and move to shallower gas targets. If necessary, we can submit this asap to document our intentions to not produce from the T -40A sand. Assuming the plugs isolating the T -40 & T -40A in both Ba -18 & Ba -32 and future planned wellwork, will a spacing exemption be required for the recently submitted sundry for Ba -27? Please let me know if you have any questions. Chris Kanyer Reservoir Engineer ckanyer@hilcorp.com Direct: (907) 777 -8377 Mobile: (907) 250-0374 From: Davies, Stephen F (DOA) [ mailto :steve.davies(aalaska.gov) Sent: Thursday, September 13, 2012 7:48 AM To: David Buthman Cc: Chris Kanyer Subject: RE: Sundry: MGS ST 17595 -27 (PTD 183 -116) David, In the absence of pool rules, statewide well spacing requirements apply. For gas wells, 20 AAC 25.055(a)(2) states: "for a well drilling for gas, a wellbore may be open to test or regular production within 1,500 feet of a property line only if the owner is the same and the landowner is the same on both sides of the line." For gas wells, 20 AAC 25.055(a)(4) also states: "if gas has been discovered, the drilling unit for the pool is a governmental section; not more than one well may be drilled to and completed in that pool on any governmental section; a well may not be drilled or completed closer than 3,000 feet to any well drilling to or capable of producing from the same pool." Per 20 AAC 25.990 (14), "complete" means to equip and condition a well as an oil, gas, or service well so that it is capable of producing or injecting fluids; in the case of a well branch in a previously completed well, "complete" means to equip and condition a well branch so that it is capable of contributing to the well's production or injection of fluids; Per 20 AAC 25.990 (26), "fluid" means any material or substance that flows or moves, whether in a semi - solid, liquid, sludge, gaseous, or other form or state; In Baker 27, if Hilcorp perforates a reservoir sand that is: 1) open to another well in the same governmental section, 2) open to another well within 3000', or 3) open within 1500' of a property line, then a spacing exception is needed. The spacing exception application process is presented in 20 AAC 25.055(d), and it usually requires 6 to 7 weeks (including a mandatory 30 -day public comment period). The application must also present a brief explanation as to why 2 • t . the operator has chosen to drill the specified location, rather than a location that conforms to the spacing requirements. AOGCC's regulations are available online through this hyperlink: AOGCC Regs Hyperlink . Please let me know if you have any questions. Thanks, Steve Davies AOGCC 907 - 793 -1224 From: David Buthman [mailto:cibuthman Sent: Wednesday, September 12, 2012 3:30 PM To: Davies, Stephen F (DOA) Cc: Chris Kanyer Subject: Sundry: MGS ST 17595 -27 (PTD 183 -116) Hi Steve, Chad informed me that you had inquired about the sundry submitted today for MGS ST 17595 -27 (Ba -27) (PTD 183 -116). We plan to perforate and test two upper Tyonek gas zones identified in this well T -40 & T -40A. Historically, gas wells MGS ST 17595 -14 (Ba -14), MGS ST 17595 -18 (Ba -18), & MGS ST 17595 -32 (Ba -32) have produced from this "undefined gas pool ". Since the Baker 18 is not currently capable of flowing gas from the T40 or T40a sandstones, do we need a spacing exception for the Baker 27 well, considering the take points are only 986' away? Current status of each gas well on Baker: MGS ST 17595 -14 (Ba -14) —Open to T -31, well is produced intermittently if fuel gas supply pipeline to platform freezes. Originally produced from T -35A (plugged back). MGS ST 17595 -18 (Ba -18) — Open to T -40A, unable to flow from zone, water production. MGS ST 17595 -32 (Ba -32) —T -40 plugged back, unable to flow from zone without well intervention. Please advise. Rgds, David B. Buthman Senior Geologist Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 dbuthman @hilcorp.com office: 907- 777 -8375 3 • mobile: 907 - 854 -4543 4 STATE OF ALASKA ALAS. )OIL AND GAS CONSERVATION COMM,)ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 79' 8. Property Designation: Baker Platform 11. Present Well Condition Summary: Total Depth measured 11,600 true vertical 9,257 Effective Depth measured 9,950 true vertical 7,691 Casing length Size Structural Conductor Surface 3407' 13-3/8" Intermediate Production 7565' 9-5/8" Liner 11127' 7" Perforation depth: Measured depth: none True Vertical depth: none Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): RECEIVED SEP .2 6 2005 Stimulate U AlaMEfJila Gas Co C .. Waiver D Time Extension 0- ns. OmmlSSIC n Re-enter Suspended Well DAnchorage 5. Permit to Drill Nùmber: Exploratory D 183-116 Service0 6. API Number: 50-733-20368-00 9. Well Name and Number: MGS ST 17595 27 (Ba-27) 10. Field/Pool(s): A Oil; B C AND DOll; E F AND G Oil Plug Perforations LJ Perforate New Pool D Perforate D 4. Current Well Class: Development D Stratigraphic D feet feet Plugs (measured) Cement Plug: lS - 5,553'; SS - 5,336' Junk (measured) feet feet MD TVD Burst Collapse 2951' 2730 psi 1130 psi 6763' 6820 psi 3330 psi 6569' - 8790' 9690 psi 7820 psi 3407' 8844' 8590'-11127' ~GANNEJ) NO'! 0 ~} 2005 3-1/2" (dual), N-80. SS @ 7,016'; lS @ 7,051' n/a Treatment descriptions including volumes used and final pressure: n/a RBDMS BFL SEP 2 8 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 375 psi 000 15. Well Class after proposed work: ExploratoryD Development D 16. Well Status after proposed work: OiID Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prin::~a:~: ?~~9~~c/ Form 10-404 ~ 04~004 ð 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations x Contact J. Gary Eller 263-7848 Oil-Bbl o o Tubing Pressure 55: 325 psi; L5: 160 psi o Service 0 GINJ D WINJ 0 WDSPl D Sundry Number or N/A if C.O. Exempt: 305-212 Title Drilling Manager Phone 907-276-7600 Date 9/26/2005 AFE 164422 ORIGINAL Submit Original Only ) )lker Platform t Well No. 27 UNOCAL As Abandoned 8-26-05 CASING AND TUBING DETAIL Mudline Elevation -102' SIZE WT GRADE CONN MIN 10 TOP BTM. 32" Structural 117' MSL -185'MS 13-3/8" 54.5,61, K-55, N-80 BTC 12.415 119' MSL 3,407' 68 9-5/8" 40,43.5, S-95 BTC 8.535 121' MSL 8,844' i. ~ 53.5,47 7" 29,35 S-95 BTC 6.004 8,590'KB 11,592' Tubing ,Long String 3-1/2" 9.2 N-80 TDSSC 2.992 282' MSL 333'RKB Short String 3-1/2" 9.2 N-80 TDSSC 2.992 282 'MSL 333'RKB SS: Tag cement at 5,336'. Tubing punches 4,839' - 4,841 '. (8/16/0§) LS:Ta cement¡a 5,553'.'· Tubing t, . punches fòi' . 2nd slage "". cement plug at 6,149"- 6,155'.' .' (8/16/05)," . " , ,~ r " , . '---- ,..."11'" r" :¡ :" . I ., '", .¡.. ~ I l. I~ , t .1 ......... ,. '...." f , "I:' ,~ II~ I'" . '., ':. ,'t ,~ I::;;~j-~ ~ ,.~ -~' :11 BP at 9950' 0ì'L- -œ m- =i.I ~ - - -~ ìZC ~ '" 10 JEWELRY D.ET AIL 00 I ,Item Lon~ Strin~ NO. I Depth 333'RKB 7039' 7051 ' 3-1/2" TDS 9.2#,Tbg with spcl couplings Kobe Model B Pump Cavity 3-1/2" Butt WLEG Short Strin~ 333'RKB 3-1/2" TDS 9.2# Tbg with spcl couplings 7006' 3-/2" TDS Box x 2-3/8" EVE 8RD Pin x/over 7016' 2-3/8" 4.6# N-80 EVE 8RD Pup PERFORATION HISTORY Zone Top Htm Date Comments A 7105 7146 Squeezed A 7252 7350 Squeezed B-1 7476 7578 Squeezed B-2 7668 7765 Squeezed B-3 7778 7875 Squeezed C-l 7938 7993 Squeezed C-2 8072 8163 Squeezed C-3 8180 8262 Squeezed C-4 8274 8328 Squeezed D-l 8476 8511 Squeezed 0-2 9968 10052 0-3 10758 10931 Squeezed 0-3 10932 10938 0-3 10939 10953 Squeezed 0-3 10954 10960 'O-~ 10961 10973 Squeezed 0-3 10974 10980 0-3 10981 11114 Squeezed PBTD = 11,592' TD = 11,600' MAX HOLE ANGLE = 60° @ 10,900' Ba-27 Final Schematic Revised by DED Well Name Ba-27 Primary Job Type Abandon Zone Jobs Lease/Serial ADL0017595 primary Well bore Affected Main Hole AFE No. ac Eng 164422 Daily Operations 8n/2005 00:00 - 8/8/200500:00 opera.iionsSummary--- -.-------., Circulate well clean. Bullhead 120 bbl (475 sx) of 14.5 ppg "G" cement down the the LS tubing. Squeeze 89 bbl into the open perfs with final squeeze pressure of 1160 on the 9-5/8" casing. Open up returns on the SS tubing and 9-5/8" casing, circulate 31 bbl of cement up these strings. Displace LS tubing with 53 bbl of seawater. Equalized pressure on LS, SS, and 9-5/8". WOC. ..8!ª!_~ºº~ºº:ºº~_~/~/~0()~ ºº:ºº, Operations Summary Pressure test LS tubing to 1600 psi - good. Pressure test SS tubing to 1500 psi - good. Attempt to pressure test the 9-5/8" casing, but unable to get a pressure test. 8/9/200500:00 - 8/10/2005 00:00 oj:îeratlOns'Summaryn,. -, ' " -. No activity. 8/10/200500:00 - 8/11/200500:00 Operati6nssummary - No activity. 8/11/2005 00:00 - 8/12/2005 00:00 ÖperatiònsSurTlmary RU e-line. RIH in LS with 6' of 1-9/16" tubing punches. Tag cement at 6190'. PU, shoot tubing punches 6149'-6155'. POOH, RD e-line. Circulate well clean with seawater. 8/12/200500:00 - 8/13/2005 00:00 Ope'ratiöns 'sÙmmarÿ Finish circulating well clean. Circulate 50 bbl of 14.5 ppg "G" cement down the LS while taking returns up the 9-5/8" casing. Applying 1000 psi squeeze pressure on the 9-5/8". Displace LS tubing with 49 bbl seawater. Equalize LS tubing and 9-5/8" casing. Maintain 1 000 psi on both strings using test pump while WOC. 8/13/2005 00:00 - 8/14/2005 00:00 Operatiöns'Summary ..... . .,.".. ,.. .... I, pressure test 9-5/8" casing to 1500 psi - good. No pressure increase noted on SS or LS tubing. Manifold SS, LS, and 9-5/8" together, perform bundle test to 1500 psi - good. 8/14/2005 00:00 - 8/15/2005 00:00 opiÚaÜons Sümmary Bundle test SS tubing, LS tubing, and 9-5/8" casing to 1500 psi for AOGCC witness. RU e-line on LS. RIH with 5' of 1-9/16" tubing punches. Tag top of cement at 5553' (AOGCC witnessed). PU, shoot tubing punches 5035'-5040'. POOH, RD e-line. 8/15/2005 00:00 - 8/16/2005 00:00 operaii"önssummary" >~c:> ~~~ï.~i~X,:,..__ 8/16/2005 00:00 - 8/17/2005 00:00 op-ëra.iròn's ·Sü·mma¡y"' P"'" . ....".. £!~,,~~lj~~.?0.~~' p~.I~..~j,th?'~!,.~ ~9/1.?"tu.~.i~9P~nc~.~~·I~~~~~ent at 5336': .~lJ,,_~.~~?~.tu.,~i~gp'u.~~h.~s at 4839'-4841'. POOH, RD e-line. 8/17/200500:00 - 8/18/200500:00 Operatiòns·sumrrîary--' , . . ... No 8/18/2005 00:00 - 8/19/2005 00:00 o-PërätiöñsŠ-ümmarY--·.._...m._.~..."..__...'" ,_. ---" ^ ..... . ......... .--...." -',-" Circulate well full.()!.9..:~pp~.NaCI brine. 8/19/200500:00 - 8/20/200500:00 . operätiõn's'SummarŸ' , No a~~~i!x.,.._.._. 8/20/200500:00 - 8/21/2005 00:00 öpë/"ätionsSummary'-- .., .. No activity. -.,-, .....--"...-..,-......,,-......,....,-....- 8/21/200500:00 - 8/22/200500:00 j operai¡6nssummary' . ,.",. . ,.. . M'. . ,I No activity. ~ .,..... "."""p.,,-, ..', 1 8/22/200500:00 - 8/23/2005 00:00 "ò"peräÜ6nssürriñiä;Y"- .-. - .,.. . . No activity.. -.. "., --,... ..--. _.._-"._"..._......,"-.~...._",..,- .. .0. ... ._.._......_._....... ... . --..-.-... -...-"........-.- ._..._......." _.'_'_.n _._.. II I I J R m ~U\Th~::~''''~_ï'I''~w ¡ ! ¡ , Daily Operations 8/23/200500:00 - 8/24/2005 00:00 op'ãrii¡¡ons-Summary m No activity. _ _,,___,..., ..m... _ __ 8/24/200500:00 - 8/25/2005 00:00 Opë-ratfòiìËisummäry ,.- !,_u'!1E..~.~:?_~~~.()f ~ie:~el_~()~~..!~.~_~-5/8" casing for freeze protect: Equalize 9-5/8" ~ith LS and SS tubing strings to freeze protect them. 8/25/200500:00 - 8/26/200500:00 'OperationsSummary - - - - I, No activity. 8/26/200500:00 - 8/27/2005 00:00 Òpe"ratfofls summäry \ Pressure up 9-5/8" casing to 1000 psi. ~.'-J_rT1.P 7.2 bb1c:>! d_~~e:! _~~~~..!~~_.:1.~':~~~~ c::~~in.9,for freeze prot~ct. Bled off trap~ed pressure on all strings. r ..--... ..-".- ...,.. ,..... .-.--..., ....---.....-....... ...._-.-,.....-- ... -- l·g'p~~~~p~u~~~W·~··~/2ª/g()º§.()º:()º. . '1 _!'J.()..~~tiyi,ty: ..... i 8/28/200500:00 - 8/29/200500:00 opsraÙonssÙrrirriary .... ..., .... ...... . . ..... ..... ... . No activity. i' Operations Summary No ~~!iyi!y: . , 8/30/2005 00:00 - 8/31/2005 00:00 ÖperationsSummiirŸ .... . ,... .., . .... ! No activity. 8/31/2005 00:00 - 9/1/2005 00:00 ÖpërätionsSurnmarý , No activity. LS = 0 pSi,. SS = 0 psi, 9-5/8" = 0 psi, 13-3/8" = 3~5 psi. II I !IT 100 ü! ¡~"'~·:::.Q~~-~.V II .<!IW;U·· .!.~,,,...~..,,.,,, ¡I 1~ n ~m~"~"'''m~wI'o_~'_''~:~';~ __ . . MG5 5T17595 01 162-007 -0 50-733-10067-00 P&A 7/26/1962 P&A 7/26/1962 PAN AMERICAN ADL0017595 MG5 ST 17595 02 163-008-0 50-733-10068-00 SUSP 11/16/1963 P&A 12/21/1970 PAN AMERICAN ADLo017595 MGS ST 17595 03 164-007-0 50-733-10069-00 SUSP 11/4/1964 P&A 12/21/1970 PAN AMERICAN ADL0017595 MGS ST 17595 ~\$( 04 164-006-0 50-733-10070-00 SI 10/13/1964 1WINJ 4/30/1974 UNION OIL CO OF CALI ADL0017595 MGS ST 17595 \- " 05 165-038-0 50-733-10071-00 2-01L 12/2811966 1-01L 12/25/1981 UNION OIL CO OF CALI ADL0017595 MGS ST 17595 06 166-003-0 50-733-10073-00 1-01L 6/13/1966 1-01L 6/13/1966 UNION OIL CO OF CALI ADL0017595 MGS ST 17595 07 166-005-0 50-733-10074-00 2-01L 8/9/1966 1WINJ 2/112000 UNION OIL CO OF CALI ADL0017595 MGS ST 17595 08 166-024-0 50-733-10075-00 SUSP 2/3/1967 P&A 11/11/1977 AMOCO PRODUCTION ADL0017595 MG5 ST 17595 o8RD 177-072-0 50-733-10075-01 SI 12/31/1977 1WINJ 7/24/1978 UNION OIL CO OF CALI ADLo017595 MGS ST 17595 09 166-051-0 50-733-10076-00 SI 2/17/1967 P&A 9/3/1976 AMOCO PRODUCTION ADL0017595 MGS ST 17595 o9RD 176-067-0 50-733-10076-01 P&A 10/22/1976 P&A 10/22/1976 AMOCO PRODUCTION ADLOO17595 MGS ST 17595 09RD2 176-078-0 50-733-10076-02 1-01L 1/7/1977 2WINJ 1/23/1989 UNION OIL CO OF CALI ADL0017595 MGS ST 17595 10 167-004-0 50-733-20002-00 1-01L 12/29/1967 P&A 8/26/1989 UNION OIL CO OF CALI ADL0017595 MGS ST 17595 11 167-017-0 50-733-20013-00 3-01L 9/7/1967 1-01L 3/12/1972 UNION OIL CO OF CALI ADL0017595 MGS ST 17595 12 168-029-0 50-733-20101-00 2-01L 3/31/1969 2WINJ 7112/1969 UNION OIL CO OF CALI ADL0017595 e MGS ST 17595 13 167-049-0 50-733-20039-00 2-01L 1/111968 1-01L 11/15/1971 UNION OIL CO OF CALI ADL0017595 MGS 5T 17595 14 168-009-0 50-733-20084-00 2-01L 4/8/1968 1-GAS 2/9/1982 UNION OIL CO OF CALI ADL0017595 MGS 5T 17595 15 177 -044-0 50-733-20307-00 1-01L 12/2/1977 P&A 8/26/1984 AMOCO PRODUCTION ADL0017595 MG5 ST 17595 15RD 184-134-0 50-733-20307-01 1-01L 12/3/1984 1WINJ 2/1/2000 UNION OIL CO OF CALI ADL0017595 MGS ST 17595 16 177-017-0 50-733-20300-00 1-01L 6/16/1977 1WINJ 2/1/2000 UNION OIL CO OF CALI ADL0017595 MGS ST 17595 17 185-217 -0 50-733-20381-00 1-01L 5/2/1986 1WINJ 2/1/2000 UNION OIL CO OF CALI ADL0017595 MGS 5T 17595 18 176-075-0 50-733-20296-00 SUSP 6/28/1977 1-GAS 3/15/1992 UNION OIL CO OF CALI ADL0017595 MGS ST 17595 20 185-135-0 50-733-20377-00 1-01L 11/11/1985 1-01L 11/11/1985 UNION OIL CO OF CALI ADL0017595 MGS ST 17595 23 184-011-0 50-733-20369-00 1-01L 4/7/1984 1WINJ 5/27/1996 UNION OIL CO OF CALI ADL0017595 MGS ST 17595 25 183-006-0 50-733-20364-00 P&A 4/30/1983 P&A 4130/1983 AMOCO PRODUCTION ADL0017595 MGS ST 17595 25RD 183-072-0 50-733-20364-01 1-01L 8/1011983 1-01L 8/10/1983 UNION OIL CO OF CALI ADLOO17595 MGS ST 17595 -. 27 --"'183-116-0 50-733-20368-00 1-01L 12/1511984 1WINJ 2/1/2000 UNION OIL CO OF CALI ADL0017595 MGS 5T 17595 28 193-119-0 50-733-20455-00 CO-30 3/25/1994 CO-30 3/25/1994 UNION OIL CO OF CALI ADL0017595 MGS 5T 17595 29 193-118-0 50-733-20454-00 1-01L 1/25/1994 1-01L 1/25/1994 UNION OIL CO OF CALI ADL0017595 .-. -- ...----.... -----. . --------,.._---- Well Name and Number WI Permit API # Final Status/Date Curr Status/Date Operator Lease(s) ___....._.__n,._. _...___ _ __ .'. ~_~_·_·_._'~___.U_"_._. .____..- u_u._ .__ ___'0__' -----..- ._-----_...~_..__._--,_..-. ---,--_.. - --.-.--- ,...- .--.---.,. - - ~---"-' --.--_._- _____n_.. .____._.',_'n e MGS ST 17595 30 193-120-0 50-733-20456-00 1-01L 2/27/1994 1-01L 2/27/1994 UNION OIL CO OF CALI ADL0017595 MG5 5T 17595 31 195-199-0 50-733-20469-00 1-01L 5/12/1996 1-01L 5/12/1996 UNION OIL CO OF CALI ADL0017595 MGS ST 17595 32 196-056-0 50-733-20473-00 1-GAS 12/10/1997 1-GAS 12/10/1997 UNION OIL CO OF CALI ADLOO17595 MGS ST 17595 501 165-039-0 50-733-10072-00 WTRSP 3/27/1967 WTRSP 3/27/1967 UNION OIL CO OF CALI ADL0017595 MGS ST 18743 1 164-010-0 50-733-10032-00 1-GAS 11/15/1964 P&A 2/8/1995 AMOCO PRODUCTION ADL0018743 MGS ST 18746 1 165-022-0 50-733-10066-00 SUSP 10/16/1965 P&A 4/19/1973 AMOCO PRODUCTION ADL0018746 --- ..-------- --'.-.----. -------..-......----.---.,,"...--.--...---.. 6GMNED NOV tll 2005 e e Chevron === Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com October lO, 2005 Commissioner John Norman Alaska Oil & Gas Conservation Commission 333 W. ih Avenue Anchorage, Alaska 9950 1 Re: Baker Platform Pilot Pre-Abandonment Work Summary Dear Commissioner Norman, This letter is intended to update the Alaska Oil and Gas Conservation Commission on the status of Unocal's pilot pre-abandonment work on the Baker Platform in Cook Inlet, Alaska. On October 22, 2004, Unocal proposed that a pilot program be initiated on the Baker platform to develop a safe, cost effective, and optimal method for the abandonment of multiple well bores. As noted in the letter of October 22, 2004, Unocal has operated the Baker and Dillon Platforms under a "lighthouse" mode where all oil and gas production has been shut-in. The Dillon Platform was shut-in December 2002 and the Baker Platform was shut-in August 2003. Unocal commenced the pilot study with a diagnostic program on five water injection wells and three oil wells on the Baker Platform in July 2005. The diagnostic program consisted of pressure and temperature surveys for baseline data, mechanical integrity of the completion, injectivity tests to the formation, and pressure measurement on the outer casing annuli. The injection wells initially surveyed were Baker 7, 8rd, 12, l5rd, and 27. The oil wells surveyed were Baker 13, 28, and 30. Unocal did not anticipate that any of the oil wells on the Baker platform would have a bottom hole pressure (BlIP) gradient exceeding seawater. However, when it was discovered that Baker well 28 had a static BlIP of9.0 ppg, the diagnostic program was expanded to include all of the oil wells and water injection wells on the Baker Platform as well as six wells on the Dillon Platform. The Baker water injection wells have mostly held their residual pressure since being shut-in. Their BlIP gradients range from 5.8 to 9.4 ppg. Three oil wells on the Baker platform have BlIP gradients that exceed a seawater gradient. Two additional wells have pressures that exceed an oil gradient but are below a seawater gradient. Under the right conditions, these wells could be capable of unassisted flow. The Baker Platform Well BlIP Summary is attached. The Dillon well BlIPs are all below a seawater gradient of 8.4 ppg. No additional diagnostic well work on the Dillon platform has been initiated. r'""'".. ~",J n, ., ~ 'r· ATE ~ t-' ~ \t '; !-IV Union Oil Company of California I A Chevron Company http://www.chevron.com e e Commissioner John Norman Alaska Oil & Gas Conservation Commission October lO, 2005 Page 2 No temperature anomalies were noted on the Baker platform with the exception of Baker well 28. Baker 28 exhibited a temperature anomaly at approximately 5,000 feet MD, as noted on the attached Baker Composite Temperature Chart. An assessment of Baker 28 is attached with the recommendation of no remedial activity. Chevron intends to conduct annual temperature/pressure surveys on Baker 28 to monitor the well status. There were no temperature anomalies noted on the Dillon platform wells. The pilot abandonment program commenced with plugging perforations on the water injection wells initially identified (i.e. Baker wells 7, 8rd, 12, l5rd, and 27). The plugging of the perforations received Sundry approval and the integrity testing of the cement plugs was witnessed by an AOGCC representative. In addition, perforations were plugged in the water supply well Baker 50l and in the gas well Baker 32. In light of the Chevron Corporation acquisition ofUnocal, the well plugging operations for the oil wells on the Baker platform has been omitted from the 2005 pilot program to allow time to reassess economic potential under Chevron's criteria. Furthermore, the gas potential from the Baker is also being re-assessed. To better prepare for the winter, Chevron will be applying heat on both the Baker and Dillon platforms. In addition, the wells capable of receiving a freeze protect fluid in their respective annuli will be freeze protected. If you have any questions or concerns, please contact me at 907-263-7657. SinCerelY,. .. ~ ~é'- I _ Timothy C. Brandenburg Drilling Manager ~ Attachments Cc: Dale Haines Gary Eller Union Oil Company of California / A Chevron Company http://www.chevron.com Baker Platform Well BHP Summary Last Updated: October 7,2005 Pressure Survey Measured Gradient Equivalent Mud Well Well Type Date MD (ft) TVD (ft) BHP (psia) (psi/ft) Weight (ppg) Notes Ba-4 Injector 27 -Jul-05 7850 7843 3141 0.400 7.7 Ba-5 Producer 30-Jul-05 6284 5566 2753 0.495 9.5 Ba-6 Producer 20-Jul-05 5712 5709 2811 0.492 9.5 Ba-7 Injector 7-Jul-05 6244 5630 2712 0.482 9.3 Ba-8rd Injector 7-Jul-05 7100 6937 3288 0.474 9.1 e Ba-9rd2 Injector Perfs cemented, no survey planned Ba-11 Producer 21-Jul-05 8379 8113 3273 0.403 7.8 Ba-128 Il)j~ctor 6-J ul-05 7080 6066 2976 0.491 9.4 Ba-121 Injector 16-Jul-05 7121 6106 2941 0.482 9.3 Ba-13 Producer 6-Jul-05 7916 7661 3236 0.422 8.1 Ba-14 Gas No survey Ba-15rd Injector 5-Jul-05 6480 6286 3050 0.485 9.3 Ba-16 Injector No survey Ba-17 Injector No survey Ba-18 Gas No survey Ba-20 Producer 28-Jul-05 4134 4030 1242 0.308 5.9 Obstruction in tubing at 4139' Ba-23 Injector 23-Jul-05 8841 8499 2584 0.304 5.8 Ba-25rd Producer 22-Jul-05 9495 9033 3208 0.355 6.8 Ba-27 Injector 6-Jul-05 7779 5999 2928 0.488 9.4 Ba-28 Producer 3-Jul-05 8441 5308 2497 0.470 9.0 Ba-29 Producer 28-Jul-05 7923 7594 2165 0.285 5.5 e Ba-30 Producer 4-Jul-05 10966 9109 3593 0.394 7.6 Ba-31 Producer 29-Jul-05 11433 10636 3795 0.357 6.9 Ba -32 Producer No survey ) State of Alaska Alaska Oil and Gas Conservation Commission ) MEMORANDUM TO: Jim Regg ....-; P.I. Supervisor !«i(ç'crlr-3()ç DATE: August 14, 2005 SUBJECT: Plug & Abandonement MGS State 17595 #27 Unocal, Baker platform Middle Ground Shoal pro 183-116 Sundry 305-212 THRU: FROM: Lou Grimaldi Petroleum Inspector NON- CONFIDENTIAL Range: 12W Rig Elevation: N/A Meridian: Umiat Total Depth: 11600 Section: 31 Lease No.: Operator Rep.: Shane Hauck Township: 9N Drilling Rig: None Casinq/Tubinq Data: Conductor: 32 0.0. Shoe@ 185 Surface: 133/8 0.0. Shoe@ 3407 Intermediate: 0.0. Shoe@ Production: 95/8 0.0. Shoe@ 9130' Liner: 7 0.0. Shoe@ 11592 Tubing: 0.0. Tail@ Casinq Removal: Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Pluqqinq Data: Top of Cement Depth Verified? 5553 (RKB) Yes, Wireline Bottom of Cement 9950 (est.) Pressure Test Applied Yes Type Plug (bottom up) Perforation Mud Weight above plug 9.8 Founded on Bridge plug Type Pluq Open Hole Perforation Annulus Casing Stub Surface I witnessed the verification of the bottom plug. A 1520 psi pressure test was applied on the Long String/Short String/Inner Annulus. There was a 20 psi decline initially and stabilized at 1500 psi for the last 15 minutes. AP RS rigged up and tagged the top of cement at 5553 (RKB) Top of perf's 7105 (RKB). Shot holes for circulate of kill weight brine at 5035-5040. Founded on: Bottom Bridge plug Balanced Retainer Verified? Orillpipe tag Wireline tag C.T. Tag No Attachments: ~ Distribution: orig - Well File c - Operator c - ONR/OOG c - Database c - Rpt File c -Inspector ~ÇANNED NO'J () 3 ZDD5 P and A MGS B-27 08-14-05 LG.xls 8/24/2005 Rev.:5/28/00 by L.R.G. Re: Follow-Up Squeeze Procedure for Ba-27 ) ) Subject: Re: Follow-Up Squeeze Procedure for Ba-27 From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Wed, 10 Aug 2005 08:17:05 -0800 To: "Eller, Gary" <ellerg@unoca1.com> CC: "Harness, Evan" <ehamess@unocal.com>, "Lambe, Steven SrI <lambes@unocal.com>, "Brandenburg, Tim C" <brandenburgt@unoca1.com> t S;;~-t\ P Gary, On second thought, I don't believe that you will need to send in a sundry. The work to plug Ba-27 was previously approved and due to the inability to pressure test the casing annulus some additional work is needed. You have provided what your modified plan is. This will help reduce a little paperwork. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 8/9/2005 4:44 PM: Gary, et al: By copy of this email, your proposal for the additional work on Ba-27 is accepted. I will look forward to the sundry. This message also confirms that I was not able to secure approval on the Ba-12 work and I cannot "verbal" it. Hopefully that approval will happen tomorrow. Good luck with the operations. Tom Maunder, PE AOGCC Eller, Gary wrote, On 8/9/20054:12 PM: Guys - See the proposed procedure for getting full isolation on the 9%" casing in well Ba-27. T om, I will get you a 10-403 on this as soon as possible, but I know the guys would like to tag cement and punch holes in the longstring tubing tomorrow if possible. Please let me know if there are any questions. «B-27 Follow-Up Plugging Procedure. doc» J. Gary Eller U nocal Alaska Advising Completion Engineer Office: 907-263-7848 SCi\NNED Þ¡UG U 9 20D~j Cell: 907-351-1313 1 of 1 8/10/20058:17 AM ') ) \~~ '- ~ \ (0 Well Ba-27, Middle Ground Shoals Unit Follow-Up Plugging Procedure AFE 164422 Recent Well History: On August 7,2005, a total of 120 bbl of cement was placed in well Ba-27 to plug the open perforations in preparation for final well abandonment. The following day, pressure testing showed that the short string apd longstring tubing strings were fully plugged, but a slow leak remained in the 9%" casing. It is not known whether the top of cement is below open perfs, whether there is a cement channel to open perfs, or whether there is a shallow leak in the 9%" casIng. Objectives: 1. Isolate all hydrocarbon-bearing zones as per 20 AAC 25.112(c)(1)(C) 2. Test the cement plug to verify zonal isolation and 9%" casing integrity as per 20 AAC 25.112(g) 3. Fill the wellbore with kill-weight fluid as per 20 AAC 25.112(f) Procedure: 1. MIRU electric line with grease injection on LS tubing. Pressure test lubricator and conduct pre-job safety meeting. RIH with 5' of tubing punches for 3~, 9.2 ppf tubing. Tag the wiper plug at ±61 00'. Fire tubing punches at ±30' above previous tag while holding 500 psi on both the LS and the SS tubing. POOH. Standby e-line until it is verified that we can circulate through the tubing punches. 2. Rig up to circulate filtered Inlet water (FIW) down the longstring (LS) tubing and pressure test to 3000 psi. Rig up to take returns off of the 9%" casing. Pressure test returns line to 2500 psi. Circulate FIW down the LS while taking returns up the 90/8" casing following the Driller's Method. Note: Our ability to circulate will give some indication whether the top of .~ cement in the 9%" casing is above or below the tubing punches. If unable to circulate, reload the tubing punch guns and perforate the LS tubing ±500' above the previous tubing punches. Repeat this operation until circulation is achieved. 3. Prepare to pump 50 bbl of 14.5 ppg cement to plug off the leak in the 9%" casing. Notify AOGCC with 24-hour notice of planned plugging operations. This is sufficient volume to place 780' of cement in the 9%" casing and LS tubing. Prepare to pump cement down the LS while taking returns off the 9%" casing. B-27 Follow-Up Plugging Procedure.doc August 9, 2005 ) ) Well Ba-27 Well Plugging Procedure AFE 164422 Page 2 4. Begin circulating cement down the LS tubing while continuously holding 1000 psi on the 9%" casing. After pumping 50 bbl of cement, drop a wiper dart for 3~" tubing down the LS tubing and displace with FIW to ±500' above the tubing punch holes. Ifnecessary, shut-in the returns on the 9%" casing while launching the dart in order to maintain 1000 psi on the 9%" casing. Do not exceed 1500 psi on the 9%" casing. Strap the displacement tank to ensure an accurate displacement volume if the well is on vacuum during displacement. After shut- down, trap 1000 psi on the 90/8" casing and LS tubing. 5. Wait on cement 12 hours. Monitor pressure of the LS tubing and the 90/8" casing. Maintain 1000 psi on each. 6. Pressure test LS, SS, and 9%" casing to 1500 psi. Contact Project Manager if any of these fail to pressure test. While holding 1500 psi on the 90/8" casing, pump down the 130/8" casing to verify communication with the 130/8" shoe. Monitor pressure on 20" conductor while pumping down 130/8" casing. Maximum allowable pump pressure on the 13%" casing = 1000 psi. Maximum allowable pressure on the 20" conductor = 300 psi. Freeze protect the 130/8" casing by pumping 7 bbl of base oil into the 130/8" casing. 7. MIRU electric line on LS tubing. Pressure test lubricator and conduct pre-job safety meeting. RIH with 5' of tubing punches for 3~, 9.2 ppf tubing. Tag fill, then fire tubing punches at ±500' above the tag depth while holding 500 psi on the LS tubing. POOH. RU e-line on SS tubing, pressure test lubricator. Rill with same tubing punches, tag the top of cement. Fire tubing punches in the SS tubing at ±500' above the tag depth while holding 500 psi on the SS tubing. POOH, RDMO e-line. 8. Blend 600 bbl of9.8 ppg kill-weight NaCl brine. (Note: Requires 95 lbs ofNaCl per barrel of fresh water. The freeze point of9.8 ppg NaCI brine is 5° F.) 9. Circulate kill-weight brine down the LS while taking returns up the 90/8" casing following the Driller's Method. When kill-weight brine is returned, shut in the 90/8" casing and take returns up the SS tubing while still following the Driller's Method. Secure well, RDMO pumping equipment. B-27 Follow-Up Plugging Procedure.doc August 9,2005 '.:,:."".N.'. ~ 1,?fM'~, '. . Vi rr. E'" .\,\ 01:1 ,JJ;,\\ ili l~· . ð,,\\ :\ :,,1 I', \'\ ¡ " ::¡ ',! U I ~=u ' I, I,',w) ,; ,II "U1 :liI.- ~~'.J.J.!~ ,.-::-....jr::::l ;, :1 \\ ! ~ ,I:' : . : :) :.! i il ~ " '::1, 'I ' . . I :1 ldJU 1-;'\ n G1,~ In ;7: :'M /ßi'~;\ ;, 'j 1:'\ '\1 \. U : :\....' / i\; :':'.1','\ ¡ ih" \,,, .!( 1,¡" ii,'. '." . J ; '." . "\ ' \, \, i U, '\, ¡ ':-l \ ,¡ ~ i ,=; \ i'ï "\} :1\\ iJr--;· Llu~L'Ù'~UÙ' U ¡ ¡ / ì l I f ~/ t ./ / FRANK H. MURKOWSKJ, GOVERNOR A.If~~1iA OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage Alaska 9519 ~<. .-""tt" \(P;"tl Re: Middle Ground Shoal Ba-27 Sundry Number: 305-212 SCß\.NNED J~UG 0 8 2005 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision Superior Court unless rehearing has been requested. ~~i Jar l ,/ jj, J K. N Chairman DATED this ~ay of August, 2005 Encl. UNOCALi) '-Alaska Unocal Corporation P.O. Box 196247 Anchorage. AK 99501 Telephone (907) 263-7660 August 1,2005 Alaska Oil and Gas Conservation Commission Commission Chair John Norman 333 West yth Avenue Anchorage, Alaska 99501 RECEIVED AUG 0 2 Z005 Re: Application for Well Suspension (Form 10-403) Baker Platform Well #27 . Alaska Oil & Gas Cons. Commission Anchorage Dear Commissioner Norman, Attached for your approval is an application for plugging the perforations of Baker Well #27 in the Middle Ground Shoal Unit. Unocal proposes to abandon the active water injection interval with cement and leave a 9.8 ppg kill fluid in the wellbore in accordance with AOGCC Regulation 20 MC 25.112(c).t'"\\~c- ~\"\ c:::.. "y -;> Q<l. O~ ~ The production of oil and gas from the Middle Ground Shoal Tyonek A-G sands on the Baker Platform had previously been deemed uneconomic, and the Baker Platform was shut down in 2003. Since that time, the wells have remained shut-in. Evaluation for gas potential is ongoing in intervals above the Tyonek A-G sands, and the wellbore may have future utility for gas production. Unocal proposes a phased abandonment program starting with plugging the perforated completion intervals. A pilot program has been initiated during the summer of 2005 to begin abandonment of up to 5 injectors and 3 producers. The intent of the trial zonal abandonment is to prove up a cost effective, tree-on abandonment program to be used on the remaining Baker Platform wells and Dillon Platform wells. Unocal intends to continue with the permitting of the eight (8) wells, and will continue execution of operations until freezing temperatures halt forward progress. The overall success of the abandonments and their effectiveness will be evaluated for the 2006 work program. Unocal commenced well diagnostic work on the Baker Platform in early July, 2005. The reservoir pressures in the water leg of the reservoir exceed a water gradient with the highest recorded gradient being 9.6 ppg EMW. In addition to the injection interval being charged, we found two producers with pressures exceeding a water gradient. In light of this information, UNOCAL is communicating with ADEC regarding our Spill Contingency Plan and will also better secure the wells for the 2005 / 2006 winter. The Baker well #27 attachments include: · 10-403 requesting plugging of the Tyonek Reservoir Sands A-G, · Procedure for plugging the perforations and pumping of kill fluids, · Summary of the Slickline Wells Diagnostics, Union Oil Company of California I Unocal Alaska 909 W~S\9t7 ~v7nu,e,:A~~h~oral,e, Alaska 99501 LJ t\ i lJ ! (\j 1-, _ http://www.unocal.com Commissioner John Norman, AOGCC August1,2005 Page 2 . Recent pressure and temperature profile showing confinement of fluids to the reservoir, . Current and proposed Well Schematics. If you have any questions, please contact myself at 263-7657. For any technical questions on the 10-403, please or Mr. Steven Lambe @ 263-7637 or Mr. Gary Eller @ 263-7848. Sincerely, -7- ~ C---2 -0 Tim Brandenburg Drilling Manager SSL/s Enclosure Union Oil Company of California I Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http://www.unocal.com Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: 1 . Type of Request: 011 6~~~O~,,-_.., h STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION AU~ . ,~ V\ t", APPLICATION FOR SUNDRY APPROVAL ~ 022005 r- 20 AAC 25.280 Operational shutdown U Plug Perforations 0 ,.--. Perforate New Pool 0 4. Current Well Class: Suspend U Repair well 0 Pull Tubing 0 Perforate ~lalk3 C~ ~Ñe~' CCmr.1ìss8\~erU Stimulate 0 Time Exte~R£~~e Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 1831160 ./ o 6. API Number: Development Stratigraphic o o Service 50-733-20368-00-00 PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 79' 8. Property Designation: Baker Platform 11. Total Depth MD (ft): 11 ,600' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 7,105 to 10,980' Packers and SSSV Type: 9. Well Name and Number: Ba-27 '""'~ S S~\-(¿ \~S<;5 t\~\ 10. Field/Pools(s): A OIL; B C AND DOlL; E F AND G OIL PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 9,257' Length Effective Depth MD (ft): 9,950' Effective Depth TVD (ft): 7,691' Plugs (measured): 9,950' Junk (measured): Burst Collapse MD TVD Size 3407' 13-3/8" 7565' 9-5/8" 111 27' 7" 3407' 1130 psi 2951' 2730 psi 8844' 8590'-11127' Tubing Size: 6763' 6569' - 8790' Tubing Grade: 6820 psi 3330 psi 9690 psi 7820 psi Tubing MD (ft): SS=7016', LS = 7051' Perforation Depth TVD (ft): 5,484 to 8,646' n/a 3-1 /2" (dual) Packers and SSSV MD (ft): N-80 n/a 12. Attachments: Description Summary of Proposal U Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steven Lambe 263-7357 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~ I ~C /'> ~~ 907-276-7600 Date ~-- f - D3 6' ~ é../ COMMISSION USE ONLY Date: 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: 8/5/2005 Oil 0 Gas 0 WAG 0 GINJ 0 o Service --, 0 0 Abandoned 0 0 WDSPL 0 Plugged r-- WINJ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 305 -~ Ia-.. Plug Integrity ~ BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: ~ cr,~\-.,....~___ ~~~~'\~e~"""1 ~\)ro'<::.~()"~"'::.. RBDMS 8FL AUG 0 4 2005 Date: f¡/{){ ~ COMMISSIONER APPROVED BY THE COMMISSION / . V'" '--, Form 10-403 Revised 11/2004 v' [JRIGINAL Submit in Duplicate Well Ba-27, Middle Ground Shoals Unit Plugging Procedure AFE 164422 Recent Well History: In July 2005, a gauge ring tagged fill at 7805' out the longstring of well Ba-27. A static BHP survey showed a 9.5 ppg formation gradient (2928 psi at 7779' :MD, 5914' SSTVD), and the temperature survey showed no abnormalities. The highest perforation in well Ba-27 is at 7105' :MD (5484' TVD). The longstring tubing above the Kobe pump cavity was pressure tested to 1700 psi, but the shortstring would not pressure test. ~ ':.-.)'Þ \>1(: c.\- <:.1) \ "- "L<::>\>f<: c.o...J \ ~ I ~ f\f¿ ~\") Objectives: 1. Isolate all hydrocarbon-bearing zones as per 20 AAC 25.112(c)(I)(C) 2. Test the cement plug to verify zonal isolation and 90/8" casing integrity as per 20 AAC 25.112(g) 3. Fill the wellbore with kill-weight fluid as per 20 AAC 25.112(f) Procedure: 1. Rig up to circulate filtered Inlet water (FIW) down the longstring (LS) tubing and pressure test to 3000 psi. Rig up a returns manifold and a choke off of the shortstring (SS) tubing and 9%" casing. Pressure test returns line to 2500 psi. 2. Circulate FIW down the LS while taking returns up the 9%" casing following the Driller's Method. Formation pressure = 9.4 ppg EMW, so major losses are not expected while circulating FIW. When clean returns are established, shut in the 90/8" casing and take returns up the SS tubing while still following the Driller's Method. Do not place any additional back-pressure on the well during this stage of the procedure. The objective of this step is to fill the wellbore above the tubing tail with FIW and remove all free hydrocarbons. Calculated tubular volumes are as follows: a. LS = 61 bbl b. SS = 61 bbl c. 90/8" casing below tubing tail = 57 bbl d. 90/8" x tubing anng!us volume = 367 bbl \ ~ _r , ~ 9\o-""~ ,,(:)\'>~ \ ~ """,S J. --\~:¡ "f(.~~~~'1 ò L(;)\J(t\ ~(('"1S 3. Blend 91 bbl of 14.5 ppg cement to abandon all open perfs. Notify AOGCC with ,,\..;)~ \t>\)1 24-hour notice of planned plugging operations. This is sufficient volume to place Æ?fVJ cement from the top of fill (7805') to 500' above the highest perf (planned TOC = <6/ 6605'). Prepare to pump cement down the LS while taking returns off the SS I":::> tubing and 90/8" casing simultaneously via the returns manifold. B-2? Plugging Procedure August 1, 2005 Well Ba-27 Well Plugging Procedure AFE 164422 Page 2 \ -,......\" \,~"~~ ~~~,,"-~ <:"I;:)~~ 4. Shut-in the SS tubing and 9Ys" casing. Begin bullheading cement down the LS 4 CS> ~ \.f tubing. Continue bullheading into the perfs until a total of 60 bbl of cement has ~~ exited the LS tubing (sufficient to fill the sump). The objective is to encourage r:Jf::.1YV\'~l;).. cement to get down to the top of fill at 7805'. Maximum allowable squeeze pressure on 9Ys" casing = 1500 psi. If 9Ys" casing pressure reaches 1500 psi during the squeeze, begin taking returns off the 9Ys" casing and SS tubing but adjust the choke to maintain ±1500 psi back pressure. After squeezing 60 bbl of cement out the tubing tail, reopen the returns line and finish circulating the planned cement volume. If possible, maintain only enough back-pressure to keep the cement pump from going on vacuum. Drop a wiper dart for 3Y2" tubing down the LS tubing and displace with 57 bbl FIW to 6605' MD. Strap the displacement tank to ensure an accurate displacement volume if the well is on vacuum during displacement. ~'~~\(J.<'(ë,.~~ ~() \~~ ())L .l:n1}1 ~ 9:J~ 5. Wait on cement 12 hours. While waiting, make sure that LS tubing, SS tubing, and 9Y8" casing pressure stay equalized to help ensure that the cement plug is balanced across all strings. RD cementing equipment. 6. MIRU slickline on LS tubing. Pressure test lubricator and conduct pre-job safety meeting. RIH with 2.7" gauge ring, tag wiper plug at ±6605'. POOH. RD from LS, RU on SS tubing. Pressure test lubricator. RIH with 2.7" gauge ring, tag top of cement. POOH, RDMO slickline. 7. Pressure test LS, SS, and 9Y8" casing to 1500 psi. Contact Project Manager if any of these fail to pressure test. While holding 1500 psi on the 9%" casing, pump down the 1J%" casing to verify communication with the 130/s" shoe. Monitor pressure on 20" conductor while pumping down 130/8" casing. Maximum allowable pump pressure on the 133¡ig" casing = 1000 psi. Maximum allowable pressure on the 20" conductor = 300 psi. Freeze protect the 130/8" casing by \ pumping 7 bbl of base oil into the 13%" casing. \.l()\...;)~t. ~~,"~~c..'~~-\.~c (..~~t:~ \C)C) 't>~ ()."',...~\..:>~ '"t.~~,,-~\~ ~ ~t'()\-~~~ 8. MIRU electric line on LS tubing. Pressure test lubricator and conduct pre-job ~ ~ ~t). ~ safety meeting. RIH with 5' of tubing punches for 3Y2, 9.2 ppf tubing. Fire f A1)¡\ tubing punches at ±500' above previous tag while holding 500 psi on the LS ~ \J~ tubing. POOH. RUe-line on SS tubing, pressure test lubricator. RIH with same~C)~~~~~ tubing punches to±500' above the tag in the SS tubing. Fire tubing punches in -\,,\~ \)..)\ \\ the SS tubing while holding 500 psi on the SS tubing. POOH, RDMO e-line. ~~'" \... 4 9. Blend 600 bbl of 9.8 ppg kill-weight NaCI brine. (Note: Requires 95 lbs of NaCI per barrel of fresh water. The freeze point of 9.8 ppg NaCI brine is 5° F.) "" 10. Circulate kill-weight brine down the LS while taking returns up the 9%" casing following the Driller's Method. When kill-weight brine is returned, shut in the B-27 Plugging Procedure August 1, 2005 Well Ba-27 Well Plugging Procedure AFE 164422 Page 3 9~8" casing and take returns up the SS tubing while still following the Driller's Method. Secure well, RDMO pumping equipment. B-27 Plugging Procedure August 1, 2005 . Cleettakeeltill— it Platform ell No. 27 UN0CAL 76 Current Completion (2- 28 -05) CASING AND TUBING DETAIL RKB to TBG Head = 30.25' SIZE WT GRADE CONN MIN ID TOP BTM. 32" Structural Surface -18 s M S L 13 -3/8" 54.5, 61, K -55, N -80 BTC 12.415 Surface 3,407' J 1 ,--, li 68 9 -5/8" 40, 43.5, S -95 BTC 8.535 Surface 8,844' 5 3.5, 47 7" 29, 35 S -95 BTC 6.004 8,590' 11,592' Tubing Long String 3 -1/2" 9.2 N -80 TDS SC 2.992 7,017' Short String ' 3 -1/2" 9.2 N -80 TDS SC 2.992 7,006' JEWELRY DETAIL NO. I Death I ID I OD I Item Long String s 30.25' CIW Hanger Butt Down -EUE 8RD up ' t 31.58 3 -1/2" Butt x TDS Pin Down X/O 3 -1/2" TDS 9.2# Tbg with spcl couplings i A 7039' Kobe Model B Pump Cavity B 7051' 3 -1/2" Butt WLEG Short String 30.25' CIW Hanger Butt Down -EUE 8RD Up 31.08' 3 -1/2" Butt x TDS Pin Down X/O 3 -1/2" TDS 9.2# Tbg with spcl couplings 7006' 342" TDS Box x 2 -3/8" EUE 8RD Pin x/over ' q 7016' 2 -3/8" 4.6# N -80 EUE 8RD Pup A PERFORATION HISTORY Zone Top Btm Date Comments i B A 7105 7146 —. — A 7252 7350 — Fill at 7805' B -1 7476 7578 Squeezed (7/6/05) B -2 7668 7765 B -3 7778 7875 _, — C -1 7938 7993 — C -2 8072 8163 C-3 8180 8262 - C -4 8274 8328 D-1 8476 8511 —• "; BP at 9950' l r G -2 9968 10052 G -3 10758 10931 Squeezed -7: - ..`j G -3 10932 10938 G -3 10939 10953 Squeezed — — G -3 10954 10960 •--,— G -3 10961 10973 Squeezed G -3 10974 10980 G -3 10981 11114 Squeezed PBTD = 11,592' TD = 11,600' MAX HOLE ANGLE = 60 @ 10,900' Current Completion DRAWN BY: NM " • aker Platform , ailetsiii, `� - PROPOSED- ellNo.27 UNOCAL 761 Phase I Abandonment CASING AND TUBING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM. RKB to TBG Head = 30.25' 32" Structural Surface -185 MSL' J I, 13 -3/8" 54.5, 61, K -55, N -80 BTC 12.415 Surface 3,407' 68 9 -5/8" 40, 43.5, S -95 BTC 8.535 Surface 8,844' 53.5, 47 7" 29, 35 S -95 BTC 6.004 8,590' 11,592' Tubing Long String 3 -1/2" 9.2 N -80 TDS SC 2.992 7,017' Short String 3 -1/2" 9.2 N -80 TDS SC 2.992 7,006' JEWELRY DETAIL NO. _ Depth ID 1 OD 1 Item Long String 30.25' CIW Hanger Butt Down -EUE 8RD up 31.58 3 -1/2" Butt x TDS Pin Down X/O 3 -1/2" TDS 9.2# Tbg with spcl couplings A 7039' Kobe Model B Pump Cavity B 7051' 3 -1/2" Butt WLEG Short String 30.25' CIW Hanger Butt Down -EUE 8RD Up 31.08' 3 -1/2" Butt x TDS Pin Down X/O 3 -1/2" TDS 9.2# Tbg with spcl couplings 7006' 3 -/2" TDS Box x 2 -3/8" EUE 8RD Pin x/over i 7016' 2 -3/8" 4.6# N -80 EUE 8RD Pup 1 = ------- 1 Cement plug f (proposed) PERFORATION HISTORY from top of fill Zone Top Btm Date Comments B (7805')to 6605' MD. A 7105 7146 Squeezed (proposed) A 7252 7350 Squeezed (proposed) B -1 7476 7578 Squeezed B -2 7668 7765 Squeezed (proposed) B 3 7778 7875 Squeezed (proposed) C -1 7938 7993 Covered with fill C -2 8072 8163 Covered with fill C -3 8180 8262 Covered with fill C -4 8274 8328 Covered with fill �/ ._ D -1 8476 8511 Covered with fill BP at 9950' — G-2 9968 10052 G -3 10758 10931 Squeezed G -3 10932 10938 _ — G -3 10939 10953 Squeezed — G -3 10954 10960 — G -3 10961 10973 Squeezed G -3 10974 10980 A h G -3 10981 11114 _ Squeezed PBTD = 11,592' TD = 11,600' MAX HOLE ANGLE = 60 @ 10,900' Baker 27 Phase I Squeeze DRAWN BY: NM • • • • (Unocal Well: 1B-27L 1 Field: 1 Baker 107/06/2005 Pressure (psia) 0 500 1000 1500 2000 2500 3000 0 1000 Pressure - Temperature Profile 1. Pulling out of hole from 7779' RKB 2. Well Shut -In 1\ 2000 3000 t 4000 Q d I' 5000 6000 7000 8000 50 65 80 95 110 125 140 Temperature (Deg. F) — Pressure – Perfs —Temperature Report date: 8/1/2005 Baker #27 Summary 07-06-05 Ba-27L Rig up Pollard with 2.65 gage ring - RIH with same and tag at 7,805 rkb slm - Trip for Pressurel Temperature tools - Survey in and out of hole at 60' Imin to 7,779 rkb slm - Max tool depth = 7,779 rkb slm (+1- 5,987tvd) BHP = 2,928psi at 123degF 9.4ppg mwe - DSM comment that we saw a temp abnormality starting +1- 100' above Kobe - Ba-27 Pressures during survey = LS 120psi, SS = 300psi, 9 5/8" by tubing = 350psi, 13 3/8" by 9 5/8" blinded off - Secure Well Move Pollard 07-14-05 Ba-27L - Rig up Pollard with 2.87 gage ring and wire line brush - RIH to seal nipple in Kobe assembly at 7,013 rkb slm - Brush and flush pumping down LS taking returns on SS (Note DSM comment that SS will flow at a good rate unassisted) - Trip to drop off gage ring - RIH with bradéd wire-brush - Brush Standing Valve seat at 7.033 rkb - Worked brush while flushing with RIW from 6,980 to 7,033 (60bbl total pumped - Trip wire - Injection test down LS taking returns on SS controlling returns with choke - 80 bbl pumped to clear tubing injection pressures = 1bbl/min = 375psi, 1.5 bbl/mi = 400psi, 2 bbllmin = 425psi, 2.5bbllmin = 500psi (Max pressure = 700psi) - Pumps off pressures = 10 sec = 550psi, 1min = 500psi, 2min = 475psi, 3min = 450psi, 4min = 435psi - Drop standing valve and chase to seat with Pollard - Attempt to Bundle test completion against standing valve N/G - Pressured up to 1,700psi lost 100psi each 30 sec down to 300psi - Tried test 3 times same results - Did not see any increase on 9 5/8" by tubing (However we do have a gas cap on Annulus, Did not see any increase in annulus pressure during injection test) - Equalize & pull Standing Valve took 3 runs (Last run we took flow on SS before attempting to latch plug & got a good latch) - Secured operations for P.M. 07-15-05 Ba-27L - RIH with AD-2 stop to 6964' and set. RIH with "w" circulating plug on top of AD-2 stop. Pressure test lonE-strinE tll,þiong to 1700 psi for 30 minutes - good. Prior to pumping LS = 290 psi, 9-5/8" = 350 psi. Bleed off pressure~ retrieve W plug. RIH, retrieve AD-2 stop. RD slickline. ') ) J. .~ ~~~~E :} !Æ~!Æ~:«!Æ FRANK H. MURKOWSKI, GOVERNOR AI,ASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 Re: Middle Ground Shoal Unit Platforms Dillon and Baker ~/ \ tÞ \<b :J Dear Mr. Cole: This letter confirms your conversation with Commission Engineer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approval~ because the relief you request needs to be sought through a different procedure. The intent of submitting sundry notices for each well was to establish a monthly pressure and general monitoring frequency for all wells on Dillon and Baker. There is a requirement in place for some of the water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the platforms are unmanned and not operating, it is not possible to obtain daily information. When operations were curtailed, a monthly monitoring frequency was established in the Plans of Development (POD) annually filed with the Division of Oil and Gas and Unocal desires to assure that this monitoring scheme is accepted by the Commission. As noted in the conversation, changing the monitoring frequency where presently in place and establishing a monthly monitoring frequency in general is not an action that is best accomplished with multiple sundry notices. A letter application requesting the desired monitoring schedule should be made under the applicable Area Injection Orders (AlO 7 for Baker and AIO 8 for Dillon) and Conservation Orders (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiving your letter applications. If prior monthly monitoring information has not been submitted to the Commission, that information should be llbmitted forthwith. .!:' Sincere~~ . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this £2 day of November, 2004 Ene!. SCANNEC¡ f\lfl\! {, ~1 J,. ) STATE OF ALASKA", ALASr-..A OIL AND GAS CONSERVATION COMMI~ùioN 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 of California aka Unocal 1. Type of Request: 3. Address: 7. KB Elevation (ft): 79' 8. Property Designation: BAKER 11. Total Depth MD (ft): 11600' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 7,105 to 10,980 Packers and SSSV Type: 909 West 9th Ave. Anchorage AK 99501 Total Depth TVD (ft): 9258' Length 600' 3,407' 7,565' Suspend U Repair well D Pull Tubing D Development Stratigraphic D D Perforate U Waiver U Annular Dispos. U Stimulate D Time Extension D Other 0 Re-enter Suspended Well D Monitor Frequency 5. Permit to Drill Number: Exploratory D 1831160 Service 0 6. API Number: 733-20368-00 9. Well Name and Number: / MIDDLE GROUND SHOAL // PRESENT WELL CONDITION SUMMARY // / Effective Depth MD (ft): Effective Depth TVD (ft);/ Plugs (measured): / 7691'/ / TVD / Ba-27 10. Field/Pools(s): 9950' Size MD 20" 13-3/8 II 9-5/8" 2,537' 7" Perforation Depth TVD (ft): 5,484 to 8,646 599' 2,954' 5,838' 6,568'-8,790' Tubing Grade: Junk (measured): Burst Collapse 2,107 psi 515 psi 2,734 psi 1,128 psi 6,822 psi 3,331 psi 9,689 psi 7,834 psi Tubing MD (ft): S: 3-1/2" SS: 3-1/2" Both 9.2#, L-80, TDS TBG Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal ~ Detailéd Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: LS: 7051' SS: 7016' 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil D GasD WAG D GINJ D 17. I hereby certify that the foregoing is true a correct to the best of my knowledge. Printed Nam./1 D. ~ Cole Signatur~~(U;~ð.a~ Title Contact Phone Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY Conditions of approval: Notify Commi sion so that a representative may witness Plug Integrity Other: Subsequent Form Required: Approved by: D Mechanical Integrity Test D Location Clearance RBDMS 8FL NOV 2 2 1004 APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION SCkNNEC;, NOV ,2 S 2004 tft:;4 Form 10-404.Revised 12/2003 D Service 0 Plugged WINJ D 0 WDSPL Abandoned D D 27 -Sep-2004 Sundry Number: 304 - tt3L/ D RECEIVED OCT 1 2 2004 BY ORDER cNaska Oil & Gas Cons. Commission IMåf~orage ()!~rGrN A CE COMMISSION Submit in Duplicate -- r"', .~ Unocal Corporation I (). 3- / / I P.o. Box 196247 'D L¡:J Anchorage. AK 99501 Telephone (907) 263-7805 UNOCALe ,~.. "'Alaska RE€l!lf/ID DEe 2 4 2002 4faskll 01/ ~. G. Q 8$ Co 4nchora~ CommisSion December 5, 2002 State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Attn: Tom Maunder Re: Baker 27, Application for Injection Variance Dear Mr. Maunder: A temperature survey was run on 10/01/02 for the purpose of demonstrating that Baker 27 (Permit # 1831160, API # 50-733-20368-00) is injecting into the desired Tyonek reservoirs and there is no flow into any fresh water aquifers or shallow reservoirs. I am enclosing a plot of the temperature survey and a current well bore schematic. The temperature survey plot starts approximately at the KOBE BRA and 65 feet above the perforated interval. No significant departures from the geothermal gradient are apparent on the plot apart from the expected general cooling from 2 years of water flood. The character of the plot very closely matched the survey run in March of 2000. We have been operating this well with the casing at pressure at 1800 psi. The 70% burst strength of the 9 5/8 casing is 3,833 psi assuming the presents of shallow gas sands at a pressure of 400 pSi. It is Unocal's opinion that the well can be operated safely with no risk to shallow fresh water aquifers or gas zones. Please grant us permission to continue injection into this well under the assumption that we will monitor the various annuli daily and report this data monthly, and we will run a temperature survey every two years. Also enclosed is a 10-403 for your approval. If you have any questions regarding this, please contact myself at 263-7807 or Phil Ayer at 263-7620. 9~ Jeffe J Dolan Waterflood Technician Cook Inlet Waterflood Management Enclosures Aogcc Baker 27 Application for Variance.doc jjd .. ",....... .~ ~c,.-{)3 ~ oEf-/o,/o .3 <if Lf(¡o(o) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS P.O. Box 196247, Anchorage, AK 99519 4. Location of well at surface Leg #2, Conductor #5, 1985' FNL, 584' FWL SEC 31, T9N, R12W, SM At top of productive interval 1878' FSL, 1737' FWL, SEC 30, T9N, R12W, SM Top of "A" zone 7105' MD At effective depth 3640' FSL, 1921' FWL, SEC 30, T9N, R12W, SM 9950' MD (7691' TVD) At total depth 4112'FSL,1982'FWL,SEC30,T9N,R12W,SM 11600'MD (9258'TVD) 12. Present well condition summary Total depth: measured true vertical 1. Type of Request: Abandon: Suspend: - Alter casing: - Repair well: Change approved program: Pull tubing: 2. Name of Operator Union Oil Company of California (Unocal) 3. Address 11600' feet 9258' feet Effective depth: measured 9950' feet true vertical 7691' feet Casing Length Size Structural Conductor Surface 3407 13-3/8" Intermediate 8844 9-5/8" Production Liner 3002 7 Perforation depth: measured See Attached true vertical See Attached Tubing (size, grade, and measured depth) LS: 3-1/2", 9.2#, L-80, TDS TBG @ 7051' TM Packers and SSSV (type and measured depth) None 13. Attachements Operation shutdown: - Re-enter suspended well: - Plugging: - Time extension: - Stimulate: - Variance: X Perforate: Other: 5. Type of well: 6. Datum elevation (DF or KB) Development: - 75' RKB ABOVE MLW feet Exploratory: 7. Unit or Property name Stratigraphic: Service: X MGS STATE 17595 8. Well number WELL #27 9. Permit number 83-116/93-013 10. API number 50- 733-20368-00 11. Field/Pool MIDDLE GROUND SHOAL Plugs (measured) Junk (measured) Cemented True vertical depth Measured depth 3070 sx 1400 sx 3407 8844 2954 6763 925 sx 8590'-11592' 6568'-9250' Detailed operations program: RECEIVED DEe 24 2002 AIasJèa DiI-\ fI t:'.111..... BOIi.¡ .ift!ff'.". Commission - lilll lIorage- SS: 3-1/2", 9.2#, L-80, TDS TBG @ 7016' TM Description summary of proposal: 14. Estimated date for commencing operation NA 16. If proposal well verbally approved: 15. Status of well classification as: Oil: Gas: Suspended: - Name of approver Date approved Service: X 17. I hereby certify th~fOreg ing is tr~~orrect to the best of my knowledge. Jeffe J Dolan ((/ Signed: Title: Water flood Technician FOR COMMISSION USE ONLY Conditions of approval: Notify ommission so representative may witness :¡:-Ç. ~~ \ \. '\ S "\ .......ù~lt.\U. \-~ '" APproval NO",? 0 'ì ~ q é Plug integrity_BOP T est- Location clearance ". .) 0\ - J /- ..J .)'it'SMechanicallntegrityTest '/.... Subsequent form required~- ~~r-..-\-'\t-...~~ ~~~q....~ 0(' ~~~~S~'\'.Jt.'1 "'i'(){o~ èJC)..\\'1. t'ü~~ ~ ?~'S.~~\~ Approved by order of the Commissioner ~ Date: 12/5/2002 ~~ -" Commissioner Date tfí 01 tJ 3 RBDMs SF l ("'¡nf;'-"¡ff!1 , " ' 1, ' . . ~../ i \ . I ""; í".:. . ' ! APR 1 4 2003 . . f " \ L~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 0 Baker 27 0 • Temperature Survey Analysis 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 0 500 1000 — 1500 —1/25/00 Prior to Inj. (Baseline) I 3/24/00 After 30 days of inj & SI f/71 hours 2000 - •10/01/2002 RIH — 10/01/2002 POH 2500 - — - —_ — 3000 . -- ---- - - - - -_ 1\ 3500 4000 -- 4500 5000 5500 - - 6000 6500 7000 - A 7500 B 8000 Jeff Dolan Ba -27 Temp Survey Analysis 20021022.xls Temp Analysis Chart (2) 10/22/2002 " ~ A-, ~ :',\',<, $",:, !l!"',~f""i"\I,~"~ ,',,:: ,... > ~ J ,'-F ..~', "";""1[ ,,;,', ':/' ':.'J,j'J;,-' ¡UBING DET'Ati:/Rlni 1 \,';¡~:~ "i>f¡',h.r-, ,,' "t 1 i,Ì;L"') , ' ~~'N~':"T"'f~G (POWER'tftoliSf': ,'i.f::~3'X','., ¡:/N{~ .,:t -:', ,¡ ,',':~.,'?;r~.~,;'~;~.~¡": """Vf~',~, ~x;'ttJ.il5~N; î .'", ", t," ',.. "',^":~,.."~':":-'~,',-::.'lì,~~V~A~ft.-{~U!T.-pg!lN.tUf !Y-QflJ,=--",~~~":,::'i:.:' ~,~,. ." 'j'" ',".. 'J';~";"':':~~'^"'-"""--"~'O>"'2r3,-:1::2BU1T'~WQ~Xi ... -,'Ir3\:~i , ,Of. " ,.' :::~;~. '< ' r '., ; , J) ~ 11'~1;.j Zi 1~8Ø-\æ' ,t . "~ '~-. 'r '13~,3/8;~,,-54..5,:,';<:~: ,'.....,'.; ~: ':",~".."', 4)\;:'i',;~'TDS~O/X j--¡/z'au 6RO_¡X-~;'7~~~~~' ! 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"c" 'ZONE ~rORAT'ONS---""""" -- '" . ,'" ','" " -- ,t , ,'w' , .. ~ 'lg':3äi;;" '7993""'" .' , " , ,.-', .....,. --- '... ,~-..' ,:-r" 8072'-':""816.:f-~~'w""," ,',.. -,-...... ,-,-- "",,~,,"""""", :,......,""';,..,,~'" . ,.....ß 1,80:- ~,Z62: -,q-,: ""-' , "" ,"J,." '::"::"', , 822.4~,~, 8J2a~ .., '.. ' TOP-Or- liNER ¡~ ä5~(jt-..~..:':--' "'- ,~'O" ¿ONEPE.~f:ORATJON-$ .. ,""~'" -_.._"-,,. " , ""':'.':',""::" "",:',"H'fI~:~r~:",,;i,..,,'t~.',~M~ 847,&'--851-P'" .' '-, ",... .','" "" ,_.. ..,'", ... ¡;~~~~~:~~~t~:~ D~~AB~È ~P' @ 995~'-::- ,-' .. -:"H '.... .."-""", --"'" ."'..,..,..,-,,, " ." ,. "". '.." , '.""-', , " .. '" ", ' " ¿ ',.. ',.'~'-~ ( " ", , . , ". '",,""'-'" ,..- -. ""'Gn, ZONÉ..PtRF~ArlpNS ' ."--.",."-",-1,-'-"",""""'..",,,,,.,.. ,,-...\...,,-,-, 9968' - 10052' ',J " 1Ö~r:5'~':"- '~o'i~ð'¡ ',-... "1"0954'- '1'09'60' >-, f' ,." ".-.. "'î-- '" --., , 1nn",~, 4 ~",-4Að-oo""""" -..,,' ',,""'" '," '",- ," --'," ,.., ,~",-""",- V~, IVJ;IIO , , , ", '.~ , , "", " . ..... "" ...... "" .. ""',..., , .. - ,," ..~ , . ',',.. ,..."._~,,-, ,.P8TD,@ 11070~,' 7" 29 &- Jð-# @.. H ~27' - ",." .'.. '. .~, .. -f", ,""', " - .,.. '..'" ",,"',"-' , .. .. -.. " .. .. . ,'..' ""'" .., .. ,,' , . '.. " , ,".." " , ,~,.., ,," .\,~"i'" t-"wt",O':;"'1 " " .- ',' ,,1 "" ~ ' ,.' ,:,' ( ,..,'%:tf[ , 17595 WELL NO,' 27 .. ,,~ t. ;":r""~",'; ,"'" ",.,,'" " , '.:-D~AWN;.DAG. .' (:;,..}",t~,:J:M,e~.EJ.tQN SC,HEMA!I.Ç " ,h '.. y- '--SCALE: NONE ... ., . UNION OIL. COMPANY OF CALIFORNIA ((jL)Q- UNOCAL) "'~ÐAl'E:-Q2--22,...9'3 --..- .:, ~ ,.., .. ,.,,',' ',',..y,. -';"..,>.., ",>JP.",.."",:r., "",,,."':-;; "",:::;"":;;;,:":",,,,,,".~~¡../,,\,,;. >R, epmts )SurueillBn~)Monthly In~.r~ol' VMiil'~ Monthly Injector Variance Tbg String Month Year APl No BA 27-95 Jul 200Z 7/1/02 0 0 825 1000 7/2/O2 0 0 82s 7/3J02 O 0 825 7/4J02 0 0 825 7/~,/02 8 617 1250 :I.Z~) 7/6/02 24 1825 1400 7/7/0~ 24 2850 1450 1450 7/6/02 23 1~2~ 14(50 1460 719/02 24 1757 1450 1450 ?/10/02 24 /.760 152~, 1575 ;/11 I/O~ 24 1746 ~550 1600 7112/02 24 1746 1550 1600 ?/13/02 24 1745 1550 1~00 7/14/02 24 1.745 ~5.,~0 1600 7tU¥02 23 t89S 1.650 t6r~ 7/16j02 1.4 2241. 1.200 2400 7/17/02 0 0 100O 1.200 ?/1~02 17 1.93! :L~OO 7/19/02 Z4 1621 1,500 1550 7/20/02 24 1616 1500 1550 7/~1/02 24 1611. 1500 1600 7/23/02 24 1619 1550 1600 7/24/02 24 1622 1550 1600 7j25102 24 2617 1550 1625 7/26/O2 24 1622 1550 1650 7/27102 24 1624 1~0 1650 ?/28/02 24 1626 1600 16~0 ?/29/02 24 1625 1600 1650 7/3o1o2 24 !629 16(]o P¼tfonn BAKER PLATFORM P.6 Page 1 or' 1 D~te Cre~ted 8~t10Z SCANNED MAR 1 0 2803 RECEIVED AlaikaOil& G~ Cons. Corem/Won A~oracje h~l~ :/&odisk, ~zcho~.Lmoc~l .com/d~/templates/tabul~,a~p 8/1/2002 NOV 01 '01 Monthly Injection Repox't ... E'g,g LO(. D NJLC Il MONTHLY REPORT BAKER PLATFORM :BA 2%95:507332036800801 I II ._l.I, ..il [I I Well Dite Hl~ [' Volume Tb8 9,62} Cs[ 13,375 CaS On Injec~e, d Press Press PreM , .-. -, I I .~ . BA 2%95 10/I/01 0 0 950 1125 I · n I I I I I - - BA 2%95 10/2/01 0 0 950 1100 ...J I .... Il · I [ I _ ~Jn ......... ~.--- i,BA 2%95 10/~/01 0 0 900 1100 . BA 2%-95 10/4/0 t 0 0 900 ! 075 BA 27-~5 ..... 10/5/01 0 ' 0 ' 900" 1050 i i[ kill [ -- . BA 2%95 10/6/01 0 0 g75 1050 ! II · · Il . iii [ I · .... 'BA 27-9~ 10/7/01 0 0 850. 1025 BA 2%95 10/8/01 0 -1 0 $50 ' 1000 -- ~ ' i i fi I il DA 2%95 10/9/01 0 0 850 1000 J._ i,ll II __ I -. I[- I i ,,1 'g~ 27-95 10/10/01 12 798 1450 1450 BA 2%95 10/11/01 24 2064 ! 650 1650 · ,_ . .... - ....... _ BA 27-95 10/12/01 ~0 1716 1650~ 1650 Ill I I · BA 27-95. 10/13/01 24 2039 1700 1700 .... I ,l[I BA 27-95 10/14/01 24 1996 1750 17~ 0 i. · ,.- .. .~ ~ ~. ! ......... ~ ........ BA 2%95 10/15/01 24 1980 1750 1750 BA 2%95 10/16/01 24 1962 17:$0 i750 .... .. ~! I ...... ~ .......... '~ BA~--9~ 10/17/0i 24 I93i 1750 1750 BA 2%95 I0118/01 24 1881 1750 1750 ~ , , ,,,- ..... ,L ............ BA 2%95 10/19/01 g. 24 1913 1800 1800 la I . I1 I i I I BA 2%95 10/20/01 24 190~ 1800 1800 27 17. m2 17 0 1750 BA ]g;7-95 ....10/~2/01 24 ' 200~ 1775 ' 1800 "0 ii I -111 Il Il · i ~k 2%95 10/23/01 24 '1923 1 gO0 1800 0 ....... fill I - · ii ,, , LBA 27-95 l 0/24/01 20 2052 1750 1800 ;.~ ~-7-95 10/25/0 ! 24 1 ~6 1800 ! 1t00 [BA 27-95 10/26/01 '24 --' 1924 1800 -' 1825 I i [I j ] .... BA 2%95 10/27/01 24 1920 1800 1 i Il i · ii I . BA 27-95 10/28/01 24 2005 1825 i 850 ......... Il Ill III I 'COMMENT: 2~ HRS, Il Ill ,11 J I - . -- BA 2%95 10/29/01 24 1927 1825 1850 0 Il I ,hi * i I i ~ I II BA 2%95 I0/30/01 24 1919 1825 l 850 - I I fl I I I I BA 2%95 10/31101 22 1714 1825'- 1840 ......... I lB BI I~- II I . ~ ,.llln~lll http:#kodiak.anchortown, unocal, comYSurvei!lauce/Injector_VarianceRcport.asp 11 /1/01 NVATERFLOOD INJECTOR MONTHLY REPORT BAKER PLATFORM: BA 27-95: 507332036500g01 --iT'--' I -----.--lit ..... ia'- ' --1, i- -- Well Date Hr~ Volume ThE 9.~2S On ~e~ Fr~s P~ Fros __ . .... i ,~ ,.. i ~ _ . BA 27-9~ ~/1/01 12 ~ 1 ~3~ 1~00 1600 bX'2~-9~ ' 6a/Oi" 24 1560 i~00 1675 al i ~A 2%95 6BI01 ~ 1 ~ ;6 1600 1675 BA 27~5 6/4/01 24 i 52~ 1600 '~700 0 u ..... ~. I I i l. Il iII II I f ~A ~7-95 6/~/01 24 1~20 1600 1700 BA 27~5 6/~/01 24 1522 1600 t700 ] i _Il I I . Ii I ~A27-95 " 6~/01 24 1521 t600 I700 I ~n27-9~ - ' ~/8/01 ~ 15~5 1~00 IT00 ~ I . I. ~ Ill I I ~.l I , ~ ,. .- ~ , ~A 27~5 '6110/01 24 1510 1600 1700 . .I --- ~ * ri ' · Em Il j i -. i I BA 27~5 6/11/01 6 573 1150 13 ~0 ~& ~,~5 ~/~2/o~ o o t too t2~o ~ , ~[ 1 .[ . [ t. ~ . , BA 27~5 6/13/01 0 0 'I~0 1200 ~A 2%95 6~14/01 0 0 1000 11 ~0 .... ii [ I ~_ I I I .' BA 2%95 6/! 5/01 0 0 97~ i 12~ gA 27~ 6/15/01 0 0 900 I 100 ._lB i --. Ill , a i A 27~ 6/~8/01 0 0 900 Il00 BA 27~ 6~9~ 1 0 0 9~ 1070 dim J I l- i IBA27~5 6a0)~1 0' 0 900 ...... 1050 il . t. BA27~5 6/21/01 0 ~ ~ 0 850 t0J0 i * .- : BA 27~5 6/22/01 0 0 8~0 1050 I I .I ~ II 1. ~ll ~A~J sa~m o o sso' ~ i~'~o .ji .1 I. I .I Ill t I , ii . I ~7-9~ 6/~4/01 0 0 8~0 I000 BA 27~5 6~8/01 0 0 goo 950 ~ _n - .i i f _ nA 27-~5 0ag10] 0 0 800 9~" _2 . Ill _Il rm. I . . I . n I II I I il I ' a I I la I in ,JUL 0 5 2001 Alaska Oil & Gas Oofls. An~rage 'V;/ATERFLOOD INJECTOR MONT}ILY REPORT, BAYER PLATFORM: BA 2%95: 507332036800501 Well Dnte On ~je~_ . ~r~ Press ~A'27-9~ ~/i/bl " 20 1.919 1650 ' 'i~00 [ i Il ....... llll I Il ~A 27~ ..... 5~/01 24 1717 i7~ 1750 ,....= - ......... . ~A x7-9~ ~/3/oi Z5 ]7oo .... ]7~ 175o ... ,... - .... BA 2~5 515l~1 24 16P3 1700 17~0 ..... BA27~5 516/01' 24 169~ .... 1700 1750 ..... - _ ~---~ i Fl . i i Illl BA 2%~ $/?/01 24 1690 16~0 1750 ... ii BA 27-~$ $~/01 24 1682 1650 1750 BA 1~$ S/9/0~ ~4 ~6ao ~0~0 1750 0 ~A~7-9~ 5/10/01 14 1668 1650 ........ 1750 BA 27-95 5/11ml 24 '16~0 16~0 ' 1750 . ..... .... a ..... BA 27-95 ~/12/01 24 1695 1675 17~ 0 I II I .... II ' ' ~X'~-~295 ~/t~ml 24 1694 1675 ..... 1750 BA 27~fi 5/14/0 i 24 1623 1700 1750 ......... BA 27-9~ ~/15/01 10 705 1400 122~ · .,,.. . ,,, BA 27-95 ..... 5/16101 0 0 ! I00 1275'" BA27~5 5/~8m] 5.~ 49~- 1380 1450 BA 27-95 5/19/01 24 1560 1900 1600 ., ~A27-9~ ....... ~a0/01 24 ~'- - i~4~" 15~0 162S BA27~ ................ 5~1)01 24 1518 1550 16~0 ~A 2~5 ~2/0 { 24 1528 { SS0 ! 6SO BA 27~5 5/~5/0 i 24 1525 ISS0 1650 ~A 27-95 5/24~1 24 1 ~22 1600 ~-- , , ..... m,. , BA 27-95 5~/01 24 1520 1600 1650 BA 27~5 5/26~ 1 24 1520 1650 1650 BA 27~5 5~7~ 1 24 15~ 1600 1650 ......... , ....... BA 27~9~ 5~8/01 24 { 524 1600 1700 ~ ..... I , ,,,,.. Ill I t J , Ill ~ ~7-~ ~9/01 ~t 1 ~ t¢ 1~0 1700 ~ ....... -._~ ii iiiii .... [ 24 1508 1600 1700 t~A?~ ~/~ ~/o ] ~. , ....... ":,u ,~r~ u.*.cr nn~b~.-r 571 mm lh{~ -.w'.%it, and ~i,; i.'aSe ha~ bma hlt 57 fimr~ duce 10/27/2000, RECEIVED JUN 0 5 2001 Maska 011 & Gas Cons, tlom~mss~u~ Anchora0e MAY 03 ~01 02:~AM ~-.~ ~.~ Monthly Injection Report .... . ..... . .... .... _ ...... ~ _. · ..... - .... .~_ --- WATERIFLOOD INJECTO'R MONTHLY REPORT BAKER PLATFORM: BA :27.95: 507332036800801 ' ' ' Hr9 ..... Volume '~g ' 9.625 C~g 1~.375 Cs8 I II ~.. II d I I ,- BA 2%95 4/1/01 24 I g92 1700 1700 I . II I ! I I II I · BA 2%95 4/2J01 24 1993 1700 1700 B^ 27-95 4/3/01 :24 1978 1725 1 .... BA 27-95 4/4/01 24 1984 1750 17~0 BA 272~5 4/5/01 ' ~24 2009 1750. 1750 BA 27-95 416101 23 1852 1750 1750 -- I _~. I I I I q · I BA 27-05 I/7/01 - :24 ..... 1826 17~'0 .... !750 BA 27-95 4/8/01 24 183i 1700 1700 - ' ' hA 2%95 429/01 24 tg4g 1700 , ]75'0 BA 2%95 4/10/01 21 1721 1650 1725 BA 27-95 I 4/1 i/01 23 1837 1675 1750 I I II r I I . II · I Ill BA 2%95 4i12/01 24 1848 1700 1750 0 BA 2%95 4tl 3/01 24 1842 1700 1750 ~ 27-~5' 4/14/01 21 1725 · ' 162~ 1700 BA 27.95 4/1'5/01 24 .4 1780 1650 1725 . B^ 27~5 4/16/01 24 1773 1650 1750 II .l' ] I1 _l I1 $A 2%95 4/17/0I 24 1770 1675 1750 Il II III - .~ BA 27-9~ 4118101 24 1766 1675 17~0 BA 2%95 4/19/01 2'4 1761 1675 1750 da I . I · Ill I l BA 2%95 4/20/01 24 ~ 1761 1675 1750 I .i ..... . - _. -,. , I BA 27-95 4/21/01 24 1757 1675 175o ~A 2%95 4/22/01 24 1749 1675 1750 BA27-95 ..... 4~23/01 24 ' 1747 ' 17~0 '" 1750 " · BA 2%95 4/24101 22 1637 1650 1750 I i l- I i BA 27-~5 4/25/01 ~ 24 1767 1650 1750 BA 27-95 4/26/0 i 24 1759 1650 1750 BA27-95 '4/i~/61 24 1756 16'~0 1750 BA 2%95 4/28/01 24 17~6 1700 1750 · Il . I · I I Il I il BA 2719 S 4/29/01- 24'' 1737 1700 1750 *, I I i i · · i i JlA 27-95 4/30/01 24 17211 1700 t 750 http://kodiak.ar~hortown,unocal.com/Surveillane~/Inje~tor_VarianccReport.asp 5/1/01 Monthly Injection Report WATERFLOOD IN,lECTOR MONTHLY REPORT BAKERPLATFORM:BA27-95'$07332036800801 Well Date On Injected Press Pnss Press I . i la I ~BA 2~,95 12/1/00 24 1893 1750 1750 BA 27-97 12/2/00 24 1891 1750 1750 I! I i I BA 27-95 12/3/00 24 1891 1750 1750 , .. [ f I · BA 2%95 12/4/0o 54 j 892 1750 17~50 0 BA 2%95 ' 12/~/00 . [ ..... 24 1889 1750 1750 0 il · Il III I BA 27-95 12/6/00 24 1890 ! 750 1750 0 , I i . tS , --- ' tlA 27-95 12/7/00 24 1889 1750 1750 0 · BA 2%95 12/8/00 24 1887 1750 i 750 0 BA 27-95 1219/00 24 188fi 177~ 1775 0 I11l . I Ill I I BA 27-95 12/10/00 24 1883 1775 1775 0 iiA 27-95 ' 12/11/00 24 1883 1775 '1775 ..... I1 I III I I I . BA 27-95 12/12/00 24 1883 1775 1775 i Il I Ill . BA27-95 12/13/00 2et 1885 1775 i7;75 BA27-9J' ' 12/14/00 24 181~-5 ' 1775 '177~ R~' 27-95- 12/15/00 24 1881 17'~5 1775 0 , . I - .I . BA 2%95 12/16/00 , 23 1888 1775 _ 1775 I ., I i Im ---. Il BA 27-98 12/! 7/00 24 19I S 1775 1775 fl i i. .. _~ m B--~ 27-9~5 12/18/00 24 1' 925 I S® ! 800 0 BJ("~7-95 1'2/19/00-- 24 1936 1800 1800 0 , ,, _ , ,,d i mi BA 27-9~ 12120/00 24 1941 1800 1800 0 BA 27-95 12/21/00 24 1939 1800 1800 0 II I I I I BA 27-95 12/22/00 24 1939 1800 1800 0 -~A 22/,-95 1~23/~)0 22 1848 ' 1800 ' 1800 ' 0 ...... BA27-95 'i2/24/00 ' 23,5- ' 1977 ' '1800 1800 .... 0 BA 27-95 12/25/00 24 1978 1800 1800 I i i~1 II I · BA 27-95 12/26100 24 1978 1815 1815 Il --.. Il - I Il - . I _ _ i BA 2%95 12/27/00 24 1981 1800 1820 I , 11 . l B A 27-95 t 2/28~00 24 1980 i 810 t 820 ~A ~?-95 i~/~9/oo 24 1978 1820 1830 BA2%95~' 1~/30/00 "' 24 " 1982 1828' i840 ,_, [] I i I i Il I IlL BA 2%95 12/31/00 24 1983 1810 1825 I ,.1 I i Y'~.~ ~e~ u~r w~mbvc Z~OA on thor, w~b-6-tc .,nd {h{u l~ge ha~ bcun hit 12 time.,. ~{ne~ 10~7/?.000, http ://kodiak.anchortown, uno cal.conYSm'veillance/lnjector__V arianceReport.asp 1 / 1/01 DEC 01 ~00 08:06AM ~ l~tt~?.~oI I ~~'~.~.~.,~,. Monthly Injection Report ~ ............. ~ ............... ~-~;;~ a ........ ~z .............. ~ ..... , . ,, ~ ....... __ · ..... ~ ~~ ............... ~ - · ........... WATERFLOOD LNJECTOR MONTHLY REPORT BAKER PLATFORM: BA 27.95: $07332036800S01 Ht~ Voluwm Tb~ 9.62~ Csg 13'37{] Csg Well Date On Injected Press Pr~s Press i i la i BA 2%95 11/l/00 24 1690 1580 1610 BA 2%95 11/2/00 24 1690 1580 1625 BA 27.95 11/3/00 24 1689 1590 1625 · .. ~-A ~7-95 11/4/00 24 1687 1590 1630 . Il III I BA 2'/-95 11/5/00 24 1689 1590 1640 ... BA 27-95 11/6/00 24 .... 1795 175..0 1750 .... BA 27-95 11/7/00 24 2149 1750 17~0 .... · Il .... I B--~ 27-95 ' 11/8/00' 24 2137 1750 1750 0 ii II I I I ... BA 27-95 11/9/00 24 2130 1750 1750 0 !BA 27.95 ! 1/10/00 24 2126 1750 1750 0 BA 27-95 ! 1/11/00 24 2119 1750 17~0 i Il I i i Il I I ...... BA 2%95 ! 1/12/00 24 2118 1775 1775 0 fi'/~ 27.95 11/1~/o~" 24 ~11~' ~77~ 17:~5 BA 27-95 11/14/00 24 2091 177~ 1775 ... BA 2%95 11/15/00 24 2040 1175 1 ii I ii il i i! DA 27-95 I 1 / 16/00 24 2039 1750 1750 n a mi i im i . . BA 2%95 11 / 17/00 24 2042 1750 1750 BA 2%95 11~i$/00 24 2040 1750 1750 .......... i ~11 BA 27-95 11/19/00 24 2034 1750 1750 I I I1 _ I I1 I ~l . I · BA 2%95 11/20/00 24 2032 1775 1775 0 BA 27.95 1 l~/~-i)~)0 22 1914 --' 1775 1775 0 BA 27-95 11/22/00 24 1986 1750 1750 0 I I Illl I III Ill BA 27-95 11/23/00 24 1985 1750 1750 ' 0 n la· i I iiii BA 27-95 11/24/00 24 191~2 1750 ! 750 0 BA 27-95 11/25/00 24 1983 1750 1750 0 nil · ISm I IIr BA 2%95 11/26/00 20 1756 1725 1725 0 n ...... II I a i a I BA 27-95 11/27/00 24 1904 1740 1750 .. I I Il 1·1 Il BA 27-95 11128/00 24 1899 1740 1750 iii Illfl I I ~1 _ I BA 2~i9~~ 11/29/00 24 1898 1750 1750 I a I . r II I .... BA 2%95 11/30/00 24 1897 1750 1750 · il iii I Il Il You :~m m~,r nomb~n' I055 on Uti, wcbs[l¢ ~nd thi~ p,n.~t: ha~ bee~ hit ~3 time· due, 10/27~,000. http://kodiak, anchortown, uno~.eom/Survcillancc/injector_VarlanceReport.asp 12/1/00 Monthly Injection Report ...... . -. - ~ ........ ,,. ,~ · ................ ~ .......... ~ - · ..... ~. ~ ~. ~: - .. ~ _ - ............ , .... ~ ~ -~ ....... ~_ ) ~ ~ .. ,~.. . .. ~ ...... ~ ......... , .. ~ ............ WATERFLOOD INJECTOR MONTHLY REPORI' BAKEK PLATFORM: BA 2%95: 507332036800501 .11 i i i ii i / in i Well Dote H~s Volume TI~ 9,62sC.qg 13.37~ 6A 27.95 ' 10/1}00 ~ 1092 1650 1650 i a ii i f i i la i BA 2%95 101~00 24 l ~90 1660 1660 I I II I I II I BA~.95 10/3/00 24 1988 1700 1675 ~ 2%95 ' 10/4/00 24 1982 1680 167~ ~A 2%95 ' ~ 10/5l~ 24 1980 1700 1~00 _._ BA 27-95" 10~6100 24 1980 17~ ' 1700- " I I I I II -- I BA 27-95 10/7/00 21 1980 1700 1700 0 I i i i i Il , ,eA 27.95 10/W00 24 1978 1700 ~00 'aA27-95 i~/O/00 , 24' , 1976 ..' 170o 17~ , [ t -- ii i i i BA 27-95 10/11/00 24 1978 1700 1700 0 i i ii . i ~A 27-95 10/12/00 23 1929 1700 1700 0 BA 27.95~ 10/13/00 ~ 1983 1700 1700 0 ii i i ii i ~27-95 -- lO/in/oo ~ ' 'z~7s ~oo ~7oo o i i i .i i ~27-~s io/~/oo 24 ~7~ ~7oo ~7o~ o , . i i . i I . i BA 27-95 I0/16/~ 12.fi 160~ 1600 1600 0 ii ,i i i BA27*S ~0/~7/~ 24 199I 16~0 16~0 ~A'2%95 ' .. 10/18/00 ~- ' 1'~8 ' i67~ 167~ .... i i II I I I II II I BA 27-95 10/re/00 24 1~0 1700 1~ n ii ~ ii BA 27-9~ 10/10/00 17 1 ~5 162~ 162~ BA27-95 10/21/00 t4 1954 - 1700 1700 ii i i '- i ,m -' BA 2%95 I0/22/00 14 1973 1725 1725 ., ii ,, i i i , i ~A 27-9~ I0/23/00 24 1965 1700 1700 i II I I I I I BA 27-95 10~4/00 24 1964 '1700 1700 0 ii i ii i i i BA 27~5 10/26/00 24 1667 ! 570 162~ 0 al i i i iii i i ~ ill ~A 27-95 l 0/26/~ 24 i540 1 ~ 50 1600 0 Ill I I I I I I BA 2%95 10/27/00 24 153 ~ [ 550 1600 II I ] II I ~ II I I ~A 27-95 10128/00 24 154~ 1525 16~ i i i i i t~A 2~;95 10/29/00 24 1620 1525 - 1600 _. Il II I _, . III BA 27-95 t0/30/~ 23.5 1 ~93 15~0 1600 -- i i [ i i i i i i [BA 27-9~ t0/31/00 24 1694 ! 575 t610 ' ' i i m i a i i http ://ko diak,anchorto wn. unoeal.com/Survcillance/Injector_VarianceReport.asp 11 / 1/00 i~U~.~.~~ Monthly Injection Report _ . ......... . ........ . ........... . ....... WATERFLOOD INJECTOR MONTHLY REPORT BAKER PLATFORM: BA 27-95: 507332036800,~101 Ht~ Volume Tbg 9'62S Csl~1 3.375 Csl~ Well Date On Injeated Pres~ Pre~s Press -- n i · i BA 2%95 't/1/60 24 1751 1400 1450 60 '~A 2%95 '- ~/2/00 24 1806 " ' 1¢50 14:~'0 48" BA 27-95 7/3/00 24 1871 1450 1500 48 I I III 1 BA 27-95 7/4/00 24 185 8 i450 1500 I .. I I I1 I BA 27-95 7/5/00 24 1865 1450 1500 i II ~ I L I Il ii BA 2%95 7/6100 24 1723 1450 700 48 nA2%95 " 7/7/00 24 ' .1855 - 1450- 1500 ' I mi · I I II B^2`7.98 7/8/00 24 1857 145o 15oo BA2,~.95 ' 7/3/00 "24 " 1848 ' i450 ' 1500 BA 27-95 ' 7)t0/00 "' 24 1861' L' i45o " 1475 .... I mm Is I I I BA 27-95 7/11/00 24 1861 1480 1490 i II II I I I i I BA 27-95 7) 12/00 24 1860 1500 1500 , m I m I _-. I ! I mi BA 27.~5 7/13/00 20.75 1736 1450 1450 BA 27-9~ 7t14/00 24 1313 1475 1475 BA 27-95 7/1~/00 24 1860 1475' 1475 __ m I . i I BA 27-95 7/16/00 24 1851 1500 1500 ill_. m i m m . BA 27-95 7/17/00 24 1 gS0 1500 1500 0 i II i i I mm i i ii BA :~7-9~ 7/! 8100 24 ! 868 1500 ! 500 0 BA 27-93 7/19/00 24 1866 1500 1500 - 0 I Ill I I BA 27-95 , 7/20/00 .24 1869 , 1500 , 1500 0 BA 27.95" '7/21/00 24 1871 1500 ! 500 O' I~ I BA 27-9~ 7/22/00 24 '1873 I S00 i 500 , i hA 27-95 ' ~/23/00 24- 18~3 1500 1'500 I i ,- ii i III BA 2%98 7/24/00 20.5 1762 1200 1300 BA 27-9'5 7/~5/Oo i7 1617 ' ~45o 14~o ' ' 11 . i i al II ~l iii i I II I I gA 2%95 7/26/00 24 1874 t 500 1500 hi II I 1 iBA 27-9~ 7/27/00 24 i856 1500 1500 Ii I/ I I ii i i BA 27-957/28/00 24 2021 1550 1550 · I~A 2%95 7/29/00 24 1996 1550 1550 0 ,1! m i m II BA 27-95 ?/30/00 24 1997 1550 1550 BA 2'~-95 7/31/0~ 24 ' 2002 lsd0 " i550 '' i m ~ I mi I http://hon'~.a~hortown,un.ocal:com/Surveillance/Injector_Variancegeport.asp 8/4/00 . . Unocal Corporation Agricultural Products 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL8 April 3, 2000 n... .... 1........J"'î:.. 'f""'.' ~.' ~ .1",,= D- - ~-Æ ~! ··V·t: .. ~ "..'1" .J' "" .. ~~,~, '" ... '- A!a~aCi¡ & GaS . COmmi135Îúl1 Blair Wondzel State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive , . . . Anchorage, AK 9950þCANNED NOV {} 12005 APR 0 6 2000 Re: Middle Ground Shoal Field, Baker 15RD & 27 Temperature Survey Procedure & Analysis \ \~'!;~~:\~~ .... Dear Blair: The following procedure was utilized in running the temperature surveys on Ba-15RD & 27. A Sapphire Quick Temperature Survey probe was run on Ba-15RD & 27 to establish a baseline temperature gradient, prior to being placed on injection. The probe's recorded data points @ 1 per second and were run @ 60 fpm while making two minute stops every even 1000'. · Ba 15RD & 27 were pfaced on injection, for a period 30 days, at an average rate of 940 BWPD and 1400 BWPD, respectively, at pressures not exceeding 2500 psi. · Quartz temperature/pressure bombs, recording one data point per minute, were run at 3 fpm with the wells on a reduced injection rate of 200 BWPD. Three minute stops were made at every even 1000' while running in the hole. · The gauges were landed in the Kobe Hydraulic cavity and the wells were then shut-in for a rninum of 48 hrs to monitor temperature build-up. · The Quartz temperature/pressure bombs were then retrieved, making three minute stops every even 1000' on the way out of the hole. · A Quick Temperature Sapphire Survey tool, recording one data point per second, was run @ 60 fpm. Two minute stops were made at every even 1000' while running in the hole. An analysis of the two wells depicts the following: · Ba-27's tubulars are of good integrity and the well should be kept on injection. The only temperature anomaly is occurring at the "A" sand perforations and is representative of good zonal isolation with any shallower sand or structures. Aogcc Baker 15RD 27 Temp analysis procedure. doc 8 4/3/00 Page 1 of . . · Ba-15RD's tubulars are of questionable integrity and the well should be kept shut-in. Multiple temperature anomalies were observed above the intended zone of injection. No temperature anomaly occurred at the intended zone of injection. It is Unocal's opinion the Ba-27 well can be operated safely with no risk to shallow gas zones due to casing integrity and all fresh water aquifers are exempt. Unocal will continue injecting under our current "Variance to Inject" permission dated 2/10/00. We will continue monitoring the various annuli daily and report this data monthly, and we will run a teß\P survey every two years for comparison with the base temperature survey run on 1/25/00. Ba-15RD's temperature survey run on 3/24/00, indicates that the water injected was not goihg into the desired interval. Unocal will keep this well shut-in and continue monitoring the various annuli daily. Christopher A. Ruff Senior Reservoir Engineer Cook Inlet Waterflood Management Attachments: Wellbore diagrams for Ba-15RD & 27. Interpreted Temperature Survey charts for Ba-15RD & 27. Interpreted two day shut-in Temperature Build-up charts for Ba-15RD & 27. i\OR n ,I" MI \ -!PI '0 & Aogcc Baker 15RD 27 Temp analysis procedure. doc 8 4/3/00 Page 2 of BA PLATFORM WELL # 15 RD CURRENT COMPLETION: AUGUST 27, 1996 KB = 32' Cameron 10" Dual Hanger Long Short t 2 A 3 I - I I 4 l - -.---.-.,.,."""'..--- TOP OF 2- 7/8" TBG CUT @ 8525' , CAVITY TAIL @ 9950' FROM ORIG. COMPLETION Top of Cement @ 8593' (Hydraulically tested to 3,000 psi) 216 sx Plug f/ 9950' - 8593' L ~ PBTD = 9,950 Tag by Tubing' TD = 10,005' MAX HOLE ANGLE = 43° @ 7,700' Aogcc Baker 15RD & 27 Temp analysis & procedure CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BTM 20 91.5 CSA 616 13-3/8 54.5-68 CSA 3,507 9-5/8 43.5-47 S-95 Butt 9,470 7" 29 HC-95 Butt 6,689 10,110 Tubin2 Long String 2-7/8 6.5 N-80 Butt 32 5,388 Short String 2-7/8 6.5 N-80 Butt 32 5,388 NO. DEPTH Long String 1 33 2 5,388 3 5,389 4 5,444 Short String A 5,381 5,383 FISH Wireline Tags 11/8/96 1/22/00 JEWELRY DETAIL ITEM 3-1/2" Seal lock pin X 2-7/8" Butt Crossover 2-7/8" EVE 8rd X 2-7/8" Butt Crossover KOBE 2-1/2" Type B SN-O-IOO BHA (Pump Cavity) Guided Mule Shoe 2-7/8" 8rd pin X 2-3/8" 8rd pin--XO 2-3/8" Srd box X 2-3/8" Butt pin--XO 2-3/8" Butt box X 1-114" EVE lOrd pin 1.660" a.D. pupjt. w/ 1-1/4" EUE lOrd Wireline Exceptions 22' unfired 2-1/8" expo strip gun lost 8/19/96 at liner lap. Tagged Top of Stub @ 8,525' w/ cutter Fill Tagged @ 8232' w/ 1.875" GR Fill Tagged @ 6510' KB w/ 2.0" GR PERFORATION DATA (DIL Depths) TOP BTM ZONE SPF DATE COMMENTS 5546 5598 Al 6 2/26/97 5936 5968 A2 6 2/26/97 5976 6008 A3 6 2/26/97 6036 6058 A4 6 2/26/97 6092 6152 A4 6 2/26/97 6174 6262 BI 6 2/26/97 6326 6377 B2 6 2/26/97 6,462 6,488 CI 6 11/26/96 6495 6546 CI 6 11/26/96 6,546 6,560 C 6 8/20/96 6926 7008 D 6 11/9/96 7,054 7,070 D 10 8-27-96 7,090 7,112 D 10 8-27-% 7,503 7,518 E 4 8-27-96 7,583 7,602 E 4 8-27 -96 7,714 7,731 E 4 8-27 -96 7,766 7,780 E 4 8-27-96 8,376 8,396 F 4 8/27/96 8,958 9,072 G 4 7/29/87 Page 3 of 8 Reperfed 10/8/96 Reperfed 10/8/96 Abandoned 4/3/00 . ..-.: ~''¿;;-'':~';'~'< . ¡ i I I f ·1"7_" '<;1"54'5 ...:1. "J ..>l't-I: ., d,,·, ;:, I & 68# '@,34Q7!. !"":';t i~',~Î"';¡~~:'; ;'1 ,i' .H"·,.IJ f ;;-".~ ,:¡ ':;¡, 9-5/ª.;;40,.4,~.?,~, .' 47 & 53.5#C 75~' 7" 29 &·35# @ 1:1127' . ':~., 'i _; .:. "~ L.,....~., ~"',_ ~',_ " j s, iUEHNG DET~:R J ,,¡ 1 ¡ E1...... I)L.' ~ ¡~'.'.G H.' ·A··.~ T.~...RI ;~<.G'.B......u..~p.......~.:...~,~ 'G1JIÚ)·.':.':.:'t...p }":..'::.~'-'.'~.~ ·..~,:..:......:;.:...-..f...' .- , · . ... :::r ~- i' ~"eutT~~pr: , X;"q~Q..t¡ 3 I:~:; ~) ""..1 f;;'7...'a.;!I· 'tt!;:8Q . ... ,., ..,~t¡...- .":"0:" ,. .. ~';;~:J~~~;f~:':;~~:~":70'!·t -,' ' , ' Jr,....:, 7~;." ,···t~,!t.-, SHœT' STRING'{~ROOUCTtO~)~j,:" ";:~'--;1 ~¡~ Ä) CIWHANGER (8UTT,;;-oOWN;EUE';SFW'::Y~r.~30,~~r. . . .--' 8) 3 - 1/ 2. Burr PIN( UP.)... ras..pJN{DOWNl ¡¡",.OVER: *.31.08', C) 3-1/2" ",.2* N-80 rBG;TOS W/' $F\,œ.cI?t..GSK¡d .. w. Dr J~fl:.! ros e-0)(x2-=j/8EV-8RD"PIIil'X~OVER ! ~~Ö06', E} 2-3¡a".4.5U>l".,.80..E.U. aRt). pI..f'0;_70i6'.1. p TAIL ASSEMBLY" . \ ~.... >;; 5) J-I/2"EU~'80Jt'~'~-1/2'7BUTrX~9'P070~1'" 7).3..., 112" 9.2# N",aOBIJT-TPIJP, (.10'),-- ~- ..' . 8) 3-1/2" BUTt WtftEl.INE!E-EN~ eUICE . 70S I' tô ) "..,r ZONE ÞÊ't~FO~AtIOÑ$ 7105;-7146; ]252' ~~~§():,¿. c-!tB:~ .zONEPE~fQ~ATION5 ".74''76'.... 7578'· SQZ,o ¡'~1_'-176&- . 7788''''' 7875~ "C" ZONE P"ERF'ORÄTION$-' 1938;...7993' .'", - 8072'- 8163~ .9...._· . 8 1~m~-ª262' 821.4:~. 8328', "D"L:ONE PERfORATION-$ 8476-'-' 85 HI r ~",._ ";_"L' . "G" !ONEPtRF'ORATIONS 9968; - "1005-2í 109'31'... 1o~:saì 10954'- .. TO~60' 10974'-,tØ980'" 'rcíL 17595 WELt NO. 27 dåJ;ì.MP~.ETION ~::;c:.HEM~TIÇ UNION OIL COMPANY OF CALlFURNIA (dbo..UNOCAL) Aogcc Baker lSRD & 27 Temp analysis & procedure DRAWN:·DAC· SCALE: NONE 'DATE: '02--22-9:3 Page 4 of 8 4/3/00 Baker 15RD 1/22/00 (Prior to Injection) vs 3/24/00 (After 30 days of Injection then Shut-In for 65 hrs) Temperature Survey o o 20 120 140 160 60 40 80 100 500 1000 ~3/24/00 Quick Temp After 30 days of inj & SI f/ 65 hrs_ - 3/21/00 Temp Survey While inj 1500 I I I I "" lilt Temp Survey After 51 hrs 51 _.__._-----_.----_.__.~ 2000 ---------------~_.~------~._--_._._-~---_.~_.- 2500 . . -~-~----'-------------.~--- . . ------------- --..--~~ . . --~--'--------~----'--.---- I I .. --'._--------- 3000 3500 rTIi3~ion 4000 --------------_._--~-------------- 4500 . I ------'_.._--------- ------~. ---,-.,----.--------------..--- 5000 I , -----.----- I ---'.--'-'-~ --------------1 --'----------------.-.--------,-------,-- 5500 "'\ -----.----.---------.-..-...- ----------. ,---_.------ "----- -----.--------.-----.---- A Sands 6000 --------..----------.-.-.,---------- --.------------."-----..-..---------.-- ----------.- B Sands ----1 I 6500 - C Sands --_.,._----------------~._-_._----------~._,-----------_.__._----~----_._------ D Sands 7000 .ogcc Baker 15RD & 27 Temp analysis & procedure Page 5 of 8 4/3/00 Baker 27 1/25/00 (Prior to Injection) vs 3/24/00 (After 30 days of Injection then Shut-In for 71 hrs) Temperature Survey 30 o 150 170 110 140 160 40 50 60 70 80 120 130 90 100 500 --_._--~---~~-_.. 1000 -~---_._-------~-----~------~._._._..~ 1500, · · · ---.------------- . . -1/25/00 Quick Temp Survey Prior to Inj. -3/24/00 Quick Temp Survey After 30 days of inj & SI f/71 hours - 3/21/00 Temp Survey while Injecting .. Temp Survey after 68:45 hrs. SI. 2000 2500 -_._--~.----..._._--~--~-----~----~------~-- 3000 -.-- . . ~-----~_._------~--~~--_.--_._~ 3500 -~-_._--_..-- ---~------~--~--~----_._---~ 4000 I , ' \' , . . , ._--:------------~~ --------~--- I , , ----.-----------\--1------- . \~ . \ I _____-...--______~n .. ! '1 I \ I . \. I ~=~~: -_--~ -1-- _=~_~~~___l '\ -I ~------- ~ -----------------:t------- ---------------------------~ a ) I . II "\ ____________--------~-L--- ----1 ..;J -? , / ---------------- ----------------~------"-,----- -~~",\ - =? "OR 1'"\1 4500 5000 5500 6000 6500 7000 7500 --~-_._----_.._-~---- 8000 .ogcc Baker 15RD & 27 Temp analysis & procedure Page 6 of 8 4/3/00 Aogcc Baker 15RD & 27 Temp analysis 110 108 106 104 102 00 98 96 94 92 90 88 86 84 82 80 78 76 74 72 70 o o è\i ¿.j ~ o Q N M APR û"{) 2000 nn_~__ ._-~- '._-0 -~~_.. -- . . > j~; ~_!.-_---~ ~ 12 Hour Shut-in Period ---- - ....-.-- --_._---~- -.""-.---. --"-- -r- -,- -,- ----r- -,- -,- -,- -,- -,- -,- ~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 <Ö Ö ~ co è\i <Ö Ö ~ co è\i <Ö Ö ~ ~ è\i <Ö Ö ~ co è\i <Ö Ö C') 0 C\ .... ~ C') 0 C\ .... ~ C') 0 C\ .,... C') 0 C\ .... ~ C') 0 ti; co Ö è\i .,... ¿.j <Ö co Ö ¿.j ti; co Ö è\i .,... ¿.j <Ö co Ö ¿.j ti; co .,... .,... C\ C\ 0 0 0 0 ~ .,... .,... .,... C\ C\ 0 0 0 0 .,... .,... .,... .,... 0 0 0 0 0 ~ 0 0 0 0 0 0 0 0 0 ~ 0 0 0 0 0 0 Q 0 0 Q è\¡ è\¡ è\¡ 0 Q 0 0 0 0 M M M ~ ~ 0 0 --- --- è\¡ è\¡ è\¡ è\¡ è\¡ M M N ~ .,... N ~ ~ C\ ~ C\ ~ ~ ~ C\ C\ M C\ ~ C\ C\ ~ ~ M C\ C\ ~ C\ M M M C') M M M C') M M M C') & procedure Page 7 of 8 4/3/00 . --------- _ ~---_. ._-----~_._-- _._~!..._------ ._~-_._-------- ~---- ~ ________ u~ ______ _____~-- . Baker 15RD 51 hour Temp Build-up 3/21/00 to 3/23/00 Baker 27 68:45 Hour SBHT 110 108 -~._. 106 -----_...-~--~- 104 -~"'-'-"---------~ 102 ----- -~-"'-"-'-'~--'-"~ 100 ____,...._.______·._~_w.. 98 ·___·_________~_u....,_.__ 96 3/21/00 17:09:01 ~ 3/22/00 5:09:01 94 Sllnjection ~-- --'.-. _._-~-----.,.._- 92 ~~- --"'--~-"----- 90 ~nllr ~I Perino . ~, .--....-..--- ---~. - --'-- --- 88 ".---....- ...--- ----- -- 86 ~ .-----.- .-...........-.- 84 -_._._----~--,..-._,-.~-_._---_._- 82 .--.-,._,-- ---..'--'..,--..-.-.---- 80 78 - --.----.. '4 ")J D.iL ')0' . 76 -~--_._._--,---~.--.- -- ----._' "."'.-. ~~AE'f(- L OO--~~~~ -_....,.._-~._......_- 74 --_._-~_. ._._._--_._------~---_.__...-.._.. ¡~, ¡j" r~I'" "'" ,.. a, ,n" i1 (..~¡S lA>m:. C6mm¡$~~Jr1~~-~-~-~~- ~-~-~--~-~--~--~~~--- 72 ---~.~_..~_.._~~.__._..-_._- t\¡~ctJl,;ir~¡ge -~~--- 70 -,- , -,- -;--- -,- -,- -,- -,- ,. -,- - 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ 0 0 0 0 0 0 0 0 0 0 0 N Ö ëó ió -<t C\ Ö ëó ió -<t N Ö ëó ió -<t N Ö .... 0 v C') C\ .... 0 v C') C\ .... 0 v C') C\ .... 0 ¿,; ëó N ¿,; ëó ¿,; ëó N ¿,; ëó ¿,; ëó N ¿,; ëó ¿,; ëó .... .... C\ 0 0 .... .... C\ 0 0 .... .... C\ 0 0 .... .... 0 0 0 Q 0 0 0 0 Q Q 0 0 0 0 ~ 0 0 Q Q Q --- 0 Q 0 Q 0 0 ~ ~ 0 C\ C\ N N C') C') try try ~ .... .... .... ~ C\ C\ C\ C\ C') ~ ~ ~ ~ ~ try ~ C\ ~ try try ~ C\ C\ ~ C\ try try try C') C') try C') C') C') C') C') Aogcc Baker 15RD & 27 Temp analysis & procedure Page 8 of 8 4/3/00 . . [Fwd: Baker 15 and Baker 27 temp surveys] Subject: [Fwd: Baker 15 and Baker 27 temp surveys] Date: Fri, 31 Mar 2000 11:34:22 -0900 From: Blair Wondzcll <blair wondzell@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Ruff, Christopher A" <mffc~unocal.com> CC: Robert Crandall <bob_crandall~admin.state.ak.us>, Tom Maunder <tom maunder~admin, state.ak.us> Chris, Have you sent the temp surveys to us? It would appear that the pair would make a good example of the value of temp. surveys. If you have not yet sent us a copy of the logs, please have a set, sent to my attention. Thanks, Blair Subject: Re: Baker 15 and Baker 27 temp surveys Date: Fri, 31 Mar 2000 11:16:48 -0900 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Ruff, Christopher A" <ruffc~unocal.com> CC: Tom Maunder <tom_maunder@admin. state.ak.us> Chris, Thanks for the information. Blair "Ruff, Christopher A" wrote: > Blair, > We have completed a preliminary review of the temperature surveys on these > wells. Baker 27 looks fine and all water is going into the desired > interval. Baker 15RD shows little to no cooling anomalies which would > indicate the water is going everywhere. This makes no sense, so we have > shut in the well and will bleed off all the tubing and casing pressures, > except for 100 psi in order to monitor the pressure. > The plan is to review all the data with you next week. This will allow us > to monitor the shut-in pressures on B-15RD for a few days, re-visit the > B-15RD data for errors and prepare the data and a summary for you. > If our interpretation doesn't change we will probably run another temp > survey in order to obtain a SI MIT and leave this well shut-in until we see > significant response from the recently reactivated waterflood operations. I > am disappointed that this well hasn't performed as expected, but not > discouraged that our reactivation will be successful since this well was not > a key driver in the overall plan. Actually, if I had to pick a well to drop > from the plan this well would have probably been the one to drop. > Thanks, I will call you next week. > Chris Ruff > Senior Reservoir Engineer > Waterflood Operations > Unocal Alaska > 907-263-7830 1 ofl 3/31/00 11:35 AM Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager Wednesday, April 05, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Stephen E. McMains Subject: Middle Ground Shoals Field Ba-7, APl #50-733-10074-00 Ba-15RD, APl #50-733-20307-01 Ba-16, APl #50-733-20300-00 Ba-17, APl #50-733-20381-00 Ba-27, APl #50-733-20368-00 10-404 Conversion to Injectors Dear Mr. McMains: Please find enclosed in duplicate Form 10-404 for the conversion from oil producers to waterflood injectors for wells Ba-7, Ba-15RD, Ba-16, Ba-17 & Ba-27 If you have any questions, please contact Steve Tyler at 263-7649 or Chris Ruff at 263- 7830. Sincerely, Dan Williamson Drilling Manager RECEIVED /., 'i-~ l 0 2000 Ala~a 0ii & Gas Cons. Commission Anchorage AOGCCletter 404's 4-5-00 SLT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: X 75' RKB ABOVE MLW feet 3. Address Exploratory: 7. Unit or Property name Stratig raph ic: P.O. Box 196247, Anchorage, AK 99519 Service: MGS STATE 17595 4. Location of well at surface 8. Well number Leg #2, Conductor #5, 1985' FNL, 584' FWL SEC 31, T9N, R12W, SM WELL #27 At top of productive interval 9. Permit number/approval number 1878' FSL, 1737' FWL, SEC 30, T9N, R12W, SM Top of "A" zone 7105' MD 83-116 / 93-013 At effective depth 10. APl number 3640' FSL, 1921' FWL, SEC 30, T9N, R12W, SM 9950' MD (7691' TVD) 50- 733-20368-00 At total depth 11. Field/Pool 4112' FSL, 1982' FWL, SEC 30, T9N, R12W, SM 11600' MD (9258' TVD) MIDDLE GROUND SHOAL 12. Present well condition summary Total depth: measu red 11600' feet Plugs (measu red) true vertical 9258' feet Effective depth: measured 9950' feet Junk (measured) true vertical 7691' feet Casing Length Size Cemented Measured depth True vedical depth Structural Conductor Surface 3407 13-3/8" 3070 sx 3407 2954 Intermediate 8844 9-5/8" 1400 sx 8844 6763 Production Liner 3002 7 925 sx 8590'-11592' 6568'-9250' Perforation depth: measured See Attached true vertical See Attached Tubing (size, grade, and measured depth) LS: 3-1/2", 9.2#, L-80, TDS TBG @ 7051' TM SS: 3-1/2", 9.2#, L-80, TDS TBG @ 7016'TM RECEIVED Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary /',??~ 'JO 2000 Intervals treated (measured)ORIGINALAlaska 0il & Gas 0OHS. Commission Treatment description including volumes used and final pressure Al~c~10[a(Je Converted to an Injector 14. Representative Daily Averaqe Production or Injection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Pdor to well operation 0 0 0 0 0 Subsequent to operation 0 0 2000 BWPD 2000 2000 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: Suspended: Service: Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ~~/~_~_,j~~ Title: ~~//~~~ Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE MGS 17595 #27 PERFORATION RECORD A A B-1 B-2 B-3 C-1 C-2 C-3~ C-4 D-1 G-2 G-3 .ZONE': CONDITION OPEN 7105- OPEN 7252- SQUEEZED 7476- OPEN 7668- OPEN 7788- OPEN 7938- OPEN 8072- OPEN 8180- OPEN- 8274- OPEN 8476- ISOLATED BY CMT. 9968- RET @ 995O' SQUEEZED ISOLATED BY CMT RET @ 9950' SQUEEZED ISOLATED BY CMT RET @ 9950' SQUEEZED ISOLATED BY CMT RET @ 9950' SQUEEZED MEASURED · DEPTH:'(FT) 7146 7350 7578 7765 7875 7993 8163 8262 8328 8511 10052 10758-10931 10932-10938 10939-10953 10954-10960 10961 - 10973 10974-10980 10981-11114 ..: TRUE:VERTICAL:'.".":-.. ..... i:: D'EP~:!!'{F~. '::~;.¥:;!:. " 5485-5517 5598-5674 5845-5847 5914-5984 6000-6062 6106-6145 6200-6266 6277-6335 6340-6381 6487-6513 7707-7781 8431-8598 8599-8605 8606-8619 8620-8626 8627-8639 8640-8646 8647-8778 RECEIVED "'-' 1 0 2000 ,~iaska 0il & Gas Cons. Commission Anchorage MIT PROCEDURE for PACKERLESS INJECTION (""" .LS ,(' / g3- , II Lr Subject: MIT PROCEDURE for PACKERLESS INJECTION WELLS Date: Wed, 09 Feb 2000 08:05:44 -0900 From: Blair Wondzell <blair_wondzell@admin.state.ak.us> Internal Organization: State of Alaska, Dept of Admin, Oil & Gas To: II Ruff, Christopher All <ruffc@unocal.com> CC: Tom Maunder <tom_maunder@admin.state.ak.us> Chris, This is our interpretation of the MIT procedure that we discussed on 8FEBOO for Baker wells 15R & 27. Both wells have been shut-in for an extended period of time. Injection fluid will be filtered Cook Inlet water at -55 deg F. 1. Do a base line temperature profile from surface to top of perfs. - completed. 2. Start injection - after 14 days, run a standard step-rate-test per SPE recommended procedure. Run test to maximum allowable pressure. Repeat step-rate-test after injection pressures have stabilized. 3. After 30 days of injection, run a temperature profile making stops as in the baseline survey (if appropriate) and hang reoorder in well. Note: if the stops used in the baseline profile are not appropriate, make appropriate stops in this profile and use in all subsequent surveys in this well. 4. After 24 hours, run a temperature profile using a separate recorder. 5. After 48 hours, retrieve reoorder and run a temperature profile from the perfs to the surface using the appropriate stops. 6. Compare the latest profile to the baseline and 24 hour profiles. 7. Evaluate all data from the temperature profiles and the step-rate-test to determine if the there are indiætions of leaking casing and or upward flow behind the casing. 8. If the conclusion is that there are no æsing leaks above the zone and no upward flow behind the pipe, the well can be put back on injection. 9. Daily injection rates and tubing and surface casing pressures will be recorded daily and reported to the AOGCC monthly. 10. If injection rates or pressures or surface casing pressure indicate the possibility of a casing leak, the well will be immediately shut-in and the AOGCC notified; future operations will then be as agreed. 11. The well will be tested every two years for mechanical integrity as in the above steps or by another procedure acceptable to the AOGCC. :sct,~NNED DEC 1 9 2002 Chris, I got )Our message on the water temperature. Please look this over and lets discuss. My direct no. is 793-1226. Thanks, Blair ~r-J. \.. /' 1 of 1 2/9/009:~^ ' l , ,( ~ TO: Jack Hartz Bob Crandall Steve Davies February 2, 2000 FR: Tom Maunder RE: Injection Wells Without Packers Blair and I have received a new communication from Chris Ruff regarding MIT verification for injection wells without packers. We had previously met to discuss this matter and had determined that after reviewing the cementing records of a given well that spinner surveys augmented by water flow logs would be the investigative criteria used to demonstrate mechanical integrity. Unocal responded that they would prefer to run temperature surveys due to prior unfavorable experience with water flow logs. Unocal has within the past week run temperature surveys in the 2 wells without packers they propose to convert to injection service. They have provided that information as well as a proposed MIT verification procedure, version 3. Blair and I ask that you review the attached information and plan to meet tomorrow to discuss this matter. The goal of the meeting would be to finalize a verification method that can be used for these and other wells that do not have packers and may be proposed for injection service. Thanks, ¡f~ Tom Maunder Attachments R~,k Q,. /'2.. 0/ :2.1( hocW tQrr'dJ S ~f' - «..o:f-", - ~"I ~ 2. W.Q Q(--S :::.Ur? ----'-""".-.---""""""'" ," "",."",....'_.",-,....",_..._--- ......,.,.,.."""."'" ,.,.""..."...-,"--"""". """"""--""'-""""'-"""""-'----.""""'--'--"""-"~,,,,-"'--"-"--'~"--"-"'~-'"-"~'------...... 16 ð.. bo/ I a' p:... C> ~ Z -¡ ----~"-,_._._---".'--_....._..., , , A. L °E- e-13'- ~ --.("J, ~.,:¡,~¡::n DEC 1 9 ZO02 '" ~ ", - ".. ' Baker Packertess Waterflood Injection Wells (B-1, '3nd B-27) ~. Subject: Baker Packerless Waterflood Injection \Neils (B-15RD and B-27) Date: Tue, 1 Feb 2000 18:52:21 -0800 From: "Ruff, Christopher All <ruffc@unocal.com> To: IIWondzell, Blair E -Vendor" <Blair_Wondzell@admin.state.ak.us> cc: "'tom_maunder@admin.state.ak.uslll <tom_maunder@admin.state.ak.us>, "Tyler, Steve L. -Contradll <tylersl@Orion.UnocaLcom>, "Dolan, Jeff JII <dolanjj@Orion.Unoæl.com> Blair, Sorry I have been so long in getting back with you. I was pulled off all projects for a week to do a quick hit project and I am now back. To bring you up to date and refresh your memory... On January 6th, I sent our response to Tom Maunder's initial recommendation for procedures regarding packerless waterflood injectors at Baker. Upon further discussion with yourself, I promised to review historical temperature profiles in order to determine a good Slut-in period for future temp surveys. We looked at a lot of data and decided it would be better to conduct a test on B-15RD to determine how long we should shut-in B-15RD and other packerless wells in order to run temp SJrveys for future variance purposes. The plan we are proposing to determine the appropriate Slut-in period for future temp surveys is below. **************************************************************************** Procedure to determine future shut-in periods and obtain variances J._~ 1) Run baseline temp surveys on B-15RD and B-27 from surface to top !9P perf (Completed on 1/26/00 and 1/27/00, reSJlts attached). 2) After obtaining procedure approval, begin injection in both wells. 3) After 30 days, shutin B-15RD and immediately run in hole with temp tool to 5350'MD (inside the long string, above the KOBE ævity. 4) Record temperatures at 5350'MD for 2 days while well heats up. 5) After measuring temp at 5350'MD for 2 days, run temp profile from top perf to surface. 6) Compare B-15RD's new temp profile to base profile 7) Plot temp vs time from temperatures recorded for initial 2 day shut-in period to determine future shut-in periods for B-2? and B-15RD profiles. 8) If the AOGCC and Unocal agree on a time for future shut-in periods',sct~!\~NED OFC 1 9 2002 run the profile on B-27 after the agreed upon shut-in period. Other'A1se '- J. "!' ! ." ,-"... ,.~ redo steps 3 - 7 to determine future shut-in periods. *************************************************************************** I have also attached "Proposed MIT Verification and Monitoring Methods For Wells Without Packers (Version 3)", which was originally written by 1of2 2/2/008:44 AM Baker Packeriess Waterflood Injection Wells (B-1 ~ lnd B-27) it Tom Maunder and later modified by myself, for your approval. I am sending all the following via fax and regular maiL. B-15RD baseline temp survey and wellbore diagram B-27 baseline temp survey and wellbore diagram Proposed MIT Verification and Monitoring Methods For Wells Without Packers (Version 3) Thanks Chris Ruff Waterflood and Reservoir Mgmt Engineer Unocal 907-263- 7830 ruffc@unocal.com SCANNED DEC 1 $) 2002 2 of2 2/2/00 8:44 AM Feb.',20006:49PM UNOCAL CORP, , ( t PropOSed MIT Verification and Monitoring Methods For Wells Without Packers (Version 3) No. ìO97 p. 3 @) Wells must be screened to meet MIT Part II requirements of no upward (vertical) flow behind casing. A review of cementing operations and bond log Interpretation usually suffices. Prior to injection, conduct a baseline temperature survey of the wellbore. This survey should cover the wellbere from surface to as near the top of the open perforations as practicable. After one month of starting injection, conduct another temperature survey after the well has been shut-in for a period long enough to allow the non-injected zonas to heat up and thus identify any leaks in the casing. The above mentioned shut-In period will be determined for all future temperature surveys by completing and analyzing the procedure below. Procedure to determine future .hut-In periods and obtain variance. 1) Run baseline tamp surveys on B-15RD and B.27 from surface to top top perl (Completed on 1/25/00 and 1/27/00, results attached). 2) After obtaining procedure approval, begin InjectIon In both wells. 3) After 30 days, shutin B-15RD and ImmedIately run in hole with temp tool to 5350'MD (inside the long string, above the KOBE cavity. 4) Record temperatures at 5350'MD for 2 days while well heats up. 5) After measuring temp at 5350'MD for 2 days, run temp profile from top perf to surface. 6) Compare B-15RD's new temp profile to base profile 7) Plot temp vs time from temperatures recorded for Inftla/2 day shut-in period to determIne future shut-In periods for 8-27 and B-15RD profiles. 8) If the AOGCC and Unocalsgree on a time for future shut-in periods, run the profile on 8-27 after the Bgr69d upon shut-In perIod. Otherwise redo !Steps :3 - 7 to detGrmine future shut-In periods. On a bi-annual basis, conduct a temperature survey to demonstrate continued mechanical Integrity and injection water flow path. Injection rates and tubing, 1ubing x casing (Inner Annulus...IA) and casing x casing (Outer Annutus--OA) pressures will be recorded dally and furnished to the Commission monthly. Surlace injection pressure should not exce~d 70°10 of the burst rating of the lightest weight production casing. Provide a minimum of 24-hour notice to Commission prior to conducting the initial or annual surveys required above. SCANNED DEC 1 ~ 2001 \ \Ak- Anchorage \Groups \A OGCC\Correspondences Baker Packerless Wells version 3.doc Feb 1, 2000 :~b,', =~OO ~ ' ~. Co C' ~,t .' ' , , ; III II~r'~'^.\L ~.~-- _'ii- -" (- -Baker 15RD 1/22/00 Temperature Survey (' HO,'(1?7 ^.I ~ ¡-. ~ I 0 0 20 40 60 eo 100 120 140 160 2500 500 '000 ,[500 2000 Ba-15RD Temp Survey.xls SCANNED DEC 1. 9 2001 l~'r=1,~)P/tft::D :..;t.-..' ç ,~-,-,..... . ,----","."""----"".".. ,...",---'" "...,.",.,....-._.._"...,._..._.-...~,..:..,-,".~,,-, ".v'.""".""."""""""""""'-" . : \18ka Oil & Gas Goo s. wmrrwetan \n en 0 rage F~b, 2000 6:52PM UNOCAL CORP, ~,I 0 ' . 0 ')7 p. 5 6J ", " ( ( Baker 27 1/25/00 Temperature Survey 30 4() 50 60 70 80 90 100 110 '20 130 '40 0 esoo .. ..... ."'..... ..'." , ",."."".....,..-,......,.-.-------.----.,--..",....-...., , ,.. , .---.-"" .., ..... "...,....".. '" ..... ".""" 500 . . ,___'M'.' . . ..-.------'- 1000 -. ...----..--. . . . ........"....""... 1500 . , _..,-,--_........ . ........,....-----."..."",..""", . .... ",.'",.." 2000 """---'-""".'."" " . .. ...,..-.,....."..-,..",,""""" "',," "..... "'" 2500 -, -""..."....., . , _._-n_'" ." . , . ....".., "'-""""""" "..".'". 3000 . ,-",".'----""-."."""""" ".. "., .. .......... ....... ".._"., ",. . 31500 .. """."." .........---.. -..-...."""'" , ,...."." .. ....." 4000 '. " .-- ---,..., ,. , "."..,-..---.-..-,..-........", '" ..." ""'.0.""""'" 4500 . ". - '-"--"-"'--.' , ..... """-"'-"-"--"--"'""..", " ",.... -..".... 5000 -""."""'.'-'----"""""" " "."......--.-.-.... ".... ..", 5500 ..."".....--,-...---..........".." """""""'."'.""'-----"-----"" ... .. .." "'."""""""""""'" '" 6000.. '" .-..,.-..,....-.","...... "'" .. .. .......-,.,..--........----.-..--........".."... " ". "m"" '" ,," 7000 ..' --... .-.". . ,... """""""""""'....."....-..--..--.,---,..-"..,..,...........",,,..."""""""'" 7500 , .---.--.---..--.---....-.-.-.----............-......"....""".",," ,,'" ,. . 8000 Baker 27 Temp Survey 1-25-00.xls SCANNED DEC 1 9 2002 1/25/00 Fe b, . 2000 6: 53PM UNOCAL CORP, NO,1097 p, 6 (J) /' '\1 ~ ,i .' UDocal Corporation A¡rlcult\U'al Products 909 West 9111 Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 . Telephone (907) 263-7830 UNOCAL8 January 4, 2000 ' Tom Maunder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage! AX 99501 Re: Baker Waterflood Maximum I~eétioD PreMUre, on Wells without Packers Dear Tom: . The maximum injection pressures on Baker lSrd and 27 wiU be limited to 70% of the casing burst strcnath. Baker 15RD 4,052 psi ,Baker 27 4,133 psi In addition, a new 10-403 and supporting documentation is attached for B-15RD, which should resolve the last set of questions. Ifl can be of further assistance please don't hesitate to call mc It 263-7830 or Steve Tyler at 263-7649. Sincerely, fJ¥fff Christopher A. Ruff Senior Reservoir Engineer Cook Inlet WaterfIo'od Management ct,. t?~q /tVfrL,$ 5~ /11ft 111111 L- A rA>< ~eN{ t/t( ¡If) -. SCA~\\NEO DEC 1 9200l Aogcc Baker Max Injection Pressures on PkrLess Wells.doc 6:53PM No.'O9: P,7@ F~b.', 2000 UNOCAL CORP. (' (,' ~rATEOFALASKA I ALASKA OIL ~I~D GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request Operation ehutdown: Re-enter lIu8pftnded well: Plugging: - Time extension: SdmUI~ Va"'i1Moe: Perfor,;t;"; Other: ? 6. Type of well: B. D&tum elevation (OF or 1<8) . Development: x, 32' KB Exploratory. = 7. Unit gr PI'Qpllrty name Stratlgraphlo:, - Service: feet . , 2. Name of Operator Union on Com 8n of Cl\lIfomla UNOCAL) S. AddreSQ P.O. Box 198247 Anaho~ e, AK 991519 4. Location of well at eurlace Leg 2, Slot 7. Platfonn Baker 1;89' FNL. 593' FWL, Sea. 31, T9N, R12W,9M At top of productive Interval 3994 FNL, 17S5 FWL. See. 31, TaN, R12W, SM At effectlvv depth 4210 FNL, 11398 FWL. Sec. $1, TaN, R12W, 8M At total depth 4228' FNL., 1889' FW SeCk 31 T9N, R12W, SM 12. Pr8e8nt weR condition eummary Total depth: muuured true vertfo~1 Middle Ground Shoal 8. Well number Baker 15RD 9. Permit number 84-134 10. API number ðO~ 733.2030701 11. Field/Pool Hemlock Effeotlve depCh: mea8Urød true vertJoaI 8693 7gefS feet Plugs (meS8ured) 6693 feet f.et Junk (measured) feet Oem8nf8d M88Wred depth Tt1Je verUoRI depth 10118 9452 Caelng Structural Conductor, Surface IntermedIate ' Production Uner Perforation d,pth: Length Size 800' 20- To surf. 800' 600' 9601' 1~3I88 To surf. 31$07' '6505' SQ22' 9-ðl88 &000' 8922' 8624' S421' 71 1200 me 8689-10110' 9270'.965G' me88ured See Attachment true wrtloal 98ft Attachment Tubing (elzG, grade, and m888urød depth) Dual 2-7/8- N'80 e.81 with hydraulIc pump aHA 0 5389' MD Packers and easv (type and me~8U~d depth) ~A Detailed operattoM program: - BOP 8ketch: - .... 011: - Gill: Suepended: - 16. If proposal will vlrbally approved: Neme of approver 1 '7. I hereby oertlfy Date roved Service: e and correct to the beat of my lø,owt.dge, Tide: RØMrvoir En lneer rOA COMMISSION use ON\. Y Conditions or approval: No1lfy Commlsalon so representative may wltn811Ø ,Plug Int8griIY_- BOP Tv8L.- Looatlon 0/8&r8nO8 Meohanloallntegrlty T.1It..-- SubHquent form I'8qulred 10- Dftt8: Approval No. order of the Comrnlll8laner Comml8eloner Date Fonn 10-405 ReV Oðl161ÐB SUBMIT IN TRlf'LICATE SCANNED DEC 1 9 2002 . ~eb- --2000 6:53PM U~.JOCAl CORP- (( ,~ , No,'Or! P':1) Perforations MD (DIL Depths) " . "TVD Top Btm To~ Btm Interval ' Zone SPF Date r 5,548' 5,598' 5,472' 5,517' 52 A1 6 2126/97 5,936' 5,968' 5,814' 5,839' 32 A2 6 2/26/97 5,976' 6,008' 5,848' 5,873' 32 A3 6 2126/97 6,036' 6,058' 5,898' 5,915' 22 A4 6 2126/97 6,092' 6,152' 5,949' 5,999' 60 A4 6 2/26/91 6,174' 6,262' 6,016' 6,091' 88 81 6 2126/97 6,326' 6,377' 6,140' 6,181' 51 82 6 2126/97 6,462' 6,488' . 6,254' 6,270' 26', C1 6 11/26/98 6,495' 6,546' 6,278' 6,318' 51 C1 6 11/26/96 6,546' 6,560' 6,318' 6,334' 14 C 6 8/20/96 6,926' 7,008' 6,625' 6,690' 82 D1 6 11/9/96 7,054' 7,070' 6,731'. 6,147' . 16 D 10 1 0/8/96 7,090' 7,11?' 6,763' 6,789' 22 D 10 1 0/8/96 7,503' 7,518' ,7.090' 7,OeS' 15 E 4 8/27/96 7,583' 7,602'" 7,151' 7, 1 5S' 19 E 4 8/27/96 7,114' -7,731' 7,248' 7,263' 17 E 4 8/27/96 7,766' 7,780" 7,285' 7,300' 14 E 4 8/27/96 8,375' 8,396' 7,769' 7,786' 20 F' 4 8/27/96 SCANNED [)EC 1 ~ 2002 ~ F~b,', 2000 6:53PM UNOCAL CORP. ( UN'DCAL. t 0 ' . 0 ~ 7 p, 9 (j) ,~ "- BAKER PLA TFURM WELL # 15 RD CURRENT COMPLETION: AUGUST 27, 1996 . . , KB = 32' Cameron 10" Dual 1 . Long Short 2 3 11/8/96 Tag @ 8232' WLM w/1.875 GR. 4 Top or Stub @ 8$5' , Top or CaDlDt (J 8593' TRUed wI adtel' <JI1dnaWlca1q to 3,000 på) '., .' A FISH 22' unflred 2- 1/S. '>cp. strip gun lolt 8/1 9/98 at liner lap. .. ' ',..- " , .', \,'.. ¡ '>'F:i:"\,, , " :,', ,:r: TOPOP2-7/8" ;" ~" ::"',,,' . ,)~ . 'I' , , " , I TBOC1JI'ct t":';""':""""""-',;";"~i 8515',CAVrrYIII,""(, Y,', "..,,1 , " ,. ,,' ".,I~.. TAfi..@99S0. IIÌ._~':~:':_\":::I"'" ,,:,,'~! 2161~PluøfJ PROM ORIO.:'" , .:. ' , " ", '",; 9950' . 8593' COMPLETION-:,,","',,',"', ',';~ L,~:('.,-,",:",':"'.."'::~: """ ',,' ,', " : ~',,;':~::",~'-::---,.;.,'i. :..,' ,'.,".,." ~ L. _____.n__- """ u "'0'" ..... PBTD = 9,950 Tag by Tubing- TD = 10,005' MAX HOLE ÄNGLE = 430 @ 7,700' ~ CASING AND TUBING DETAIL SIZE GRADE T B ITO 20 91.5 CSA 616 13-3/8 54.5-68 ~SA 3,507 9-5/8 43.5-47 5-95 Butt 9,470 7" 29 HC-95 Butt 6,689 10,110 Tubi~.I; Long String 2-7/8 6.S Short String 2-7/8 6.S N-80 Butt 32 5,388 N-80 Butt 32 5,388 JEWELRY DETAIL 110. ~ Long String 1 33 2 3 . 5,388 5.389 3-1/2" Seal lock pin X 2-7/8" Butt CrossoveX' 2-7/8'" EUE 8rd X 2-7/8" Butt Crossover KOBE 2-112" Type B SNpQ-1OO BBA (pump Cavity) Guided Mule Shoe 4 5.444 Short StrIng A 5,381 ........' """"'.'-'-.'---'--"-"-'.'.""'" . .......-------.----.-..,.....-,....... -'..... ,. TOP 5'46 5936 .5976 6036 6092 6174 6326 6,462 649' 6,546 6926 7,054 7,090 7.S03 7,583 7,714 7,16G 8.376 B,9~8 8.912. 9,124 9,210 9.614 5,383 2-7/8" 8rd pin X 2-3/8" Srd pin-XO 2-3/8" 8rei box. X 2-3/8" Butt pin--XO 2-3/8" Butt box X 1-114" EUE lOrd pin 1.660" Q.D. pup jt. w/1-1I4tt EUE lOrd PERFORATION DATA (DIL Depths) BTM ZD~ sp, DATE COMMENf§ 5598 At 6 2/26/97 5968 A2 6 212619'7 6008 A3 6 2/26197 60.5S M ð '2J26197 6152 A4 6 '2126/97 6262 B 1 6 2/26/97 6377 82 IS 2126197 6,488 Cl 6 11/26196 cSS4ð C1 6 11/26196 6,560 C 6 8120196 7008 P1 6 11/9196 7.070 D 10 8.27.96 R<1>erfed .018/96 7.112. D 10 8.27.96 Repert'ed 10/8/96 7.518 B 4 8~27-96 7.602 B 4 8-27-96 7.731!. 4 9.2'7.96 7,780 B 4 8.27.96 8,396 F 4 8127/96 9,072 G-l 4 7129/87 9.072 0.1 4 1012184 9.162 0-2 4. 1012184 9..566 G-4 4 10/'2184 9.800 G.! 4 1012184 Abtl1dol1/".d Abtlðdoned AbAndoned Ab.ndoned Abandoned O:\DRll..LING\SClffiMATIC\GP\GPP\Ba-15rdSchm 8-S-97.doc REVISED: 8/5/97 5CA~~~~ED DEC 1 {} 2002 DRAWN BY: BKS P.O. Box ,ge247, Anono", e AK 99151; 4. Looation of well at surface Leg #2, Conductor *6,1988' FNL, 684' FWL SEC 31, TgN, R12W, SM At top of pruduotfve Interva' 1878' FSl, 1737' FWL, SEC 30, TeN, Rt2W. 8M Top of IN ZOh8 7106' MD At effective depth ' 3540' FSL, 1921' FWL, SEe 30, TeN, R12W, 9M ~950' MD (7eG1' TVD) AI tatal depth 4112' Fe!., 19S2' FWL. SEe 30, T9N. R12W, SM 11eoc'Me 12. Presòht wøll oondldon BUmmary , Total depth: m81i1IUred ' tnJ8 vertical , . Feb,',2000 þ8 of Requeet . , 2. NBme of Ope"'tor Union 011 Com In 3. AddrølUl etf80ttve depth: Ca.ølng StruCtUral COnductor Surface tntennedlø t8 Production Uner PlfforaUon depth: IJNOC~L COR~rATE OF ALASKA ( ALASKA OIL ~I~D GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 6:54PM Abe.ndon: Suapend: Altef callIng:- RepåirW&lI: ChDnge a roved ri,gram:: ' Pujj'h;b'n ; 11800' teet D26 8 ' fGo1 meuured tMÞ vertical 9950' feet 7891' fttet No,~097 I¡~,~ P"O~ Length Size OpøratlCln flhutdawn: R~enter llUøpended well: Pluggln9: - 11me extenwlon: StfmulQ'1ë; Var¡;-'"ce: ~er1ora¡;: Other. X- 5. Type of wttfl: 6. Dutum elevation (OF or KB) Dewelopment: X .' 75' AKa ABOVE ML W ffiet ExpIoratorv: - 1. Unit or Prop arty ~ame Strattgraphlo: = Sørvloe: MGS STATE 11!5Ð!5 8. Well number WELL m D. Permit number 83-118/ Q3-01:J 10. API number eo- 733-20388-00 11. FIeld/Pool MIDOlE @ROUND SHOAL 8407 1 So-SI8' 81M.. Do-,SlB' ßOO2 7 meaøured S- Anaahed true vertloa) See Attached F'lugs (m~81u.d) Junk (1M8eured) . Cement8d M..øurød dep1h True nrUoal depth 6070 ax 1400 ex S407 8844 29~4 87153 g26 8X 8890'..11&;2' 8568'-9260' Tùblng (1/%9, grade, and rT18uured depth) . La: 3-1/2-,9.2', L-SO. TCS TBG 07051' TM sa: ~112', 9,21, L-ao, TDS TaG 0 7018' TM . Packe", and S~SV (typ. and mea8fJrwd depth) None' 13, Attachem8nte Cø80r1pUon eummaf)' of propoeal: ' X - Re uustl tern 1'8 Irml",on to In eat for future varfa.noe re yell 14, Estlma t.d d"te for commenolng operation 1!5, Status of wøll oIuell1oatton 88: 16. If prcpoMI well verbally Approved: .... Oetalled optlr.Uons program: , - BOP ~.toh: - all: Go: SufJpønded: - Date a roved ServIce: d DOrrect to the belt of my knowledge. Dat.: { (It / , 1 TItle: Re$Øhfolt en Ineer FOR COMMISSION use ONLY Condltlona of approval: Notify Commll&lon 8ð repreeentaöv8 m.y wftn.,ee Plug Int8grlly- BOP T..L- Locøtlon oIearanoe Meohan'~1 Integrity TeeL- Sub8eqU8f1t form required 10.., , 91 "ed: order of the CommiNloner Form 10-..403 Rev 0811&'88 Approval No. Cornmlnloner Dat, SUBMIT IN TRIPLICATE "'.' ..,.".,..,..."...,.." ,....."" "^".,.",~,~"..,-.~...."...,, ',"""" "'.- f'~'i'" ~NNED DEC'~ 1:\?002 .-.." ..",..",""..-------,...--..-,".""--""""""-"""'--".,..",.....¡:)~,. ~:.j. . ..,' c, " ,,:. iJ ... ,'", .' 'Feb.' 2000 6:54PM UNOCAL CORP, No.'O37 P':@ \1 , M GS , 7595 #27 PERFORATION RECORD - . r MEAS -~- reAih"." " ,,!. i=:~.r: I .' '~~" ZONE": DEPTH:'(Fn . . ..,' , ':"~t'(Frl " " CONDITION ""'DEPJ;': ,~':'i" . I . ,;,,'. '~',:~, . A OPEN 7105- 7146 5485- 5517 A OPEN 7252- 7350 5598- 5674 B-1 SQUEEZED 7478- 7578 5845- 5847 B-2 OPEN 7668- 7765 5914- 5984 B-3 OPEN , 7788- 7875 6000- 6062 . C-1 OPEN 7938- 7993 6106- 61'45 C-2 OPEN 8072- 8163 6200- G2G6 C-3 OPEN ' 8180-8262 6277 - 6335 C-4 OPEN, 8274- 8328 6340- 6381 0-1 OPEN 8476-8511 6487-6513 G-2 ISOLATED BY CMT 9968-1 0052 7707-7781 RET @ 9950' G-3 SQUEEZED 10758-10931 8431 - 8598 ISOLATED BY CMT 10932-10938 8599-8605 RET @ 9950' , SQUEEZED 10939-10953 8606- 8619 ISOLATED BY CMT 1 0954-1 0960 8620- 8626 RET @ 9950' . SQUEEZED 10961 ...1 0973 8627 - 8639 ISOLATED BY CMT 10974-10980 Ba40~ 8646 RET @ 9950' SQUEEZED 10981-11114 8647-8778 ... " -' 5CANNE~) DEC 1. 9 2002 -"" .", "" , I Feb.'.2000 U~WCAL CORP" \{ 6:54PM t"" .... , A Co" ":'-':'. :" C.I;:; t ..' " . "'~"""'---J .::: :::,. ;:.:...1 """ll.:"7' . . - ~ Y-!I.,J I J . ,,~ ' J .. ~~ '" p rffi ~ ~ \\~ , ~} : TOP OF LINER ~ 8. 90 'Vv I , 9-5/8". 40, 4.3.5, 47 &: 53.5# ç ~ ~~~I ~ ?8TD @ 11070' .', .., ' ,," "., , ' 7" 29 & 35# @ 11 !~7 NO.1097 p, '2Q~ ." I'"~ ~ -'.:SING C¡~-,':':L ..:'.':; '~7"ING (Powe:~ F"LUIC;; "' .: ....: Þ'o1NtjER CBUTT-OO'HN. EvE ~F:D-\JP) ~ 30.25' . .::~... I .: SUrf PINtuP) ., -:~ PINtOOWN\ X-OVER to J 1.58'1 to, ! J-' ~"~.1. N...80 T6'-". -0-.> WI ~~ t:l cPtt;s . .¡\ ,!-' : ':VS sox It 3-" : EU eRa PIN x-~ 0 7017' I' . - ~ ~ .. :er. 3" '.toea "S" e\olA . 10~~;+- ';~':~ï .~rRING (PROC:UCTJcrl) .1\ CIW ,.¡ANCER (Sutr...OOWN. £'.'~ aRO-I.I~) 0 JO.25' ;) 3-tl': ~UTT PIN(UP). Wi ?'NCOOWN1 X-OVER .'031.08' ;) J-' ':'" g.~. N-80 fee. rw ~ WI '"i,P ':'.. CPLC~ ' ;:\) 3-1 ,': .~S 80~ II 2-3/8 Ell SRD ~'N X-OVER. 7008' ::) ~-Ji!" 4 4, N-80 EU BRO PuP 0 70115' . ~ -~IL ASSEMBLY ~ 1$1 3-1,':" EIJ 8RC BOX 11 3-1: .l't BUTT )(-OV£~ " 704" . 7) 3- 'I :.. ,),2' N-80 !VTT PUP ( lOt) '" !) 3- 1/:" aVTi WIAELIN£ JltE-~N'mY cute!!: 0 70S I' , . . , . , "A" ZONE ?ERFORATIC'NS' 7 tOS~- 7-146' '. .' . 7252'-7.350' "B", ZONE PERFORATICNS 7476'- 7578' sazo 7668' - 7765' ;788' - 7875' "C,. :ONE PERFORATIONS 7938' - 7993' SO72'- 8 163' a 180'- ~26.2' 8274-- SJ2B' "0" ZONE: PERFORATIONS 8475'- 8511' , qfilL~~~ B P ~ ~' "C" ZONE PERF"ORATI N 9968' - ~10052 10932'- 10938' 10954'- 109'60' '10974'-' 10980' '< -. \b- A[iL I:~, J:' '-'!ELL ~10. 27 <. .:' :""IPLETi/.)N ~:;CHEMA TIC , ¡ DRAWN: CAC : '~CALE: NCNE .- :.INI(..N O!L ::"OL':~AN,( (:r- >~L¡FI>~:NIA (::L"\~ l./NOCAL; I :;.iE: 0:-::-93 $CANNED DEC 1 9 2001 , " , ,.1, I ,. at & Gas Coos, Cornmflllön Anooorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: X 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: X 75' RKB ABOVE MLW feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: MGS STATE 17595 4. Location of well at surface 8. Well number Leg #2, Conductor #5, 1985' FNL, 584' FWL SEC 31, T9N, R12W, SM WELL #27 At top of productive interval 9. Permit number 1878' FSL, 1737' FWL, SEC 30, T9N, R12W, SM Top of 'A' zone 7105' MD 83-116 / 93-013 At effective depth 10. APl number 3640' FSL 1921' FWL, SEC 30, TgN, R12W, SM 9950' MD (7691' TVD) 50- 733-20368-00 At total depth 11. Field/Pool 4112' FSL 1982' FWL, SEC 30, T9N, R12W, SM 11600' MD (9258' TVD) MIDDLE GROUND SHOAL 12. Present well condition summary Total depth: measu red 11600' feet Plugs (measu red) true vertical 9258' feet _ Effective depth: true measured vertical 7691' 9950' feet feet Junk(measured) ORIGINAL Casing Length Size Cemented Measured depth True vertical 'depth Structural Conductor Surface 3407 13-3/8' 3070 sx 3407 2954 Intermediate 8844 9-5/8' 1400 sx 8844 6763 Production Liner 3002 7 925 ,sx 8590'- 11592' 6568'-9250' Perforation depth: measured See Attached ;¢% ?" ~"~' !'ii ~;i~'~.? ....... true vertical See Attached Tubing (size, grade, and measured depth) - ~ -..,.; ..., LS: 3-1/2', 9.2#, L-80, TDS TBG @ 7051' TM SS: 3-1/2', 9.2#, L-80, TDS TBG @ 7016' TM Packers and SSSV (type and measured depth) .~ ~ . None .,-:'_. :- '., ~-,-, :,-.. I i" 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: Requesting temporary permission to inject for future vadance request. 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify thio the best of my knowledge. Signed: Title: Reservoir Engineer Date:¢ -- ~""-//~-~f~/~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ]Approval No_?.//'.'~-~ ~-,~,-~~" -) ~ · - Plug integrity~ BOP Test Location clearanceI , 7;7/''''-'~''-~ Mechanical Integrity Test Subsequent form required lO- ORIGINAL Robert N. Christenson Approved by order of the Commissioner ~ ,'~(B Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE TOP OF LINER .¢¢.. 8~iqo_' 9-5/8" 4-0, 4..3.5, 47 & 53.5# @ ~ PBTD ("d) 11070' -'.'~ING ".3 '.]7.=,,iNO (POWE.=, FLU~'2i '" ".'.' ~a.NOER (8UI"r-0ovvN. EUE ~.=..D-,.~P) @ ..30.25' _,, _-._: 2 ~ui"r P!NfUP) ,- -"5 PINfDOWN~ X-OvER ,~ 3 1.58'1 " :-' -" '.~,2~l N-80 'rBG. 'DS w/ _:2 CL CPLO$ -~E 3" .tOOEL ","' ._~4 @ 702_;--"" '_'-=-_x: '.:: RING (PRC.'_PUCTIO;'II ClW .~."NGER (BUTT-DOwN. E'.'E 8RO-:.:P) @ 5-;,' _=UTF P,',.I(UP) :,: ';'DS -~:N(OOWNI X-OVER ~ 3 1.08' $-:'2' 9.2~ N-80 'rD0..-?.:, w/ $¢ "?L CPLO$ ,3-~, ~ 'DS 8OX x 2-,.3/8 EU 8RD ¢~1,.~ >(-OVER '"¢ 7006' 2-5;'_~'' .: 6¢ N-80 EU 8R0 .=UP ~ 7016' -;iL ASSEMDLY ,3- '.., EU 8RD BOX x 5- ~., 2" BUTT X-OVER ~ 704 1' 5-I/"" 9.2,iI N-80 8LrfT PUP f '10') 3-i/2" BUTT WIRELINE RE-ENTRY GUIDE @ 7051' "A" ZONE ?ERFORATI,_-:";S,.. 7 7252'-7350' "B" ZONE =ERFORATICN':'; 7476'- 7..578' SQZO ---, 7~68'- 77,65' 7758'- 7875' "("" '~'"' h.I C ... ..:..,.,~_ PERFORATIONS 79.38'- 799.3' 8072'- 8 165' 8 180'- 8262' 8274'- 8328' "D" ZONE PERFORATIONS 3476'- 35 I 1' ~] .~_L, ASLE BP c'O_ 9950' -:'P oos2 -- 10954'- ]0960' ',09 74.'--! 0980J '1%~ 7" 29 & 35# @ I~ !2TM i j ,Ni F)("6/, i .,, t~. '7CALE: NCNE -.:.TE: 0"-'"-93 MGS 17595 #27 PERFORATION RECORD A ZONE; CONDITION OPEN a OPEN B- 1 SQUEEZED B-2 OPEN B-3 OPEN C- 1 OPEN C-2 OPEN C-3 OPEN MEASURED · DEPTH-'(F'I') 7105-7146 .-TRUEVERTICAL . . . . . DEPTH'(FT):~.'~.:. 5485-5517 C-4 OPEN 8274-8328 D- 1 OPEN 8476-8511 6487-6513 G- 2 ISOLATED BY CMT 9968-10052 7707- 7781 RET @ 9950' G- 3 SQUEEZED 10758-10931 8431-8598 ISOLATED BY CMT 10932-10938 8599-8605 RET @ 9950' SQUEEZED 10939-10953 8606- 8619 ISOLATED BY CMT 10954-10960 8620-8626 RET @ 9950' SQUEEZED 10961 - 10973 8627-8639 ISOLATED BY CMT 10974-10980 8640-8646 RET @ 9950' SQUEEZED 10981 - 11114 8647-8778 7252- 7350 5598- 5674 7476-7578 5845-5847 7668- 7765 5914- 5984 7788- 7875 6000-6062 7938- 7993 6106-6145 8072-8163 6200-6266 8180- 8262 6277- 6335 6340-6381 Procedures to Obtain Variances on B-15RD and B-27 (version 4) Both wells have been shut-in for an extended period of time. Injection fluid will be filtered Cook Inlet water at-55 deg F. 1. Do a base line temperature profile from surface to top of perfs. - completed. 2. Start injection - after 14 days, run a standard step-rate-test per SPE recommended procedure. Run test to maximum allowable pressure. Repeat step-rate-test after injection pressures have stabilized. 3. After 30 days of injection, run a temperature profile making stops as in the baseline survey (if appropriate) and hang recorder in well. Note: if the stops used in the baseline profile are not appropriate, make appropriate stops in this profile and use in all subsequent surveys in this well. 4. After 48 hours, retrieve recorder and run a temperature profile from the perfs to the surface using the appropriate stops. 5. After retrieving the recorder, run in hole with high speed recorder which was used for Step #1. 6. Compare the series of profiles to the baseline. 7. Evaluate all data from the temperature profiles and the step-rate-test to determine if the there are indications of leaking casing and or upward flow behind the casing. 8. If the conclusion is that there are no casing leaks above the zone and no upward flow behind the pipe, the well can be put back on injection. 9. Daily injection rates and tubing and surface casing pressures will be recorded daily and reported to the ^OGCC monthly. 10. If injection rates or pressures or surface casing pressure indicate the possibility of a casing leak, the well will be immediately shut-in and the AOGCC notified; future operations will then be as agreed. 11. The well will be tested every two years for mechanical integrity as in the above steps or by another procedure acceptable to the AOGCC. Unocal Corporation Agricultural Products 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL October 26, 1999 Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Reactivation and Expansion of the Baker Waterflood Dear Blair: Due to the short economic life of oil operations in Cook Inlet and the cost to repair the waterflood facilities on the Baker platform, Unocal recently took a close look at the possibility of permanently terminating the waterflood operations on the Baker platform. After a review of the success at the Cross-Timber's A platform and realizing we could obtain variances on several wells, Unocal has decided to go forward with the reactivation and expansion of the Baker Platform waterflood. It has been down due to a series of mechanical difficulties since September 1996. The plan is to repair all the surface facilities and convert five shut-in producers to injection. No downhole modifications are planned except closing sliding sleeves and possibly perforating to improve injectivity. Three of these wells have packers and should pass conventional MIT's. The other two wells will require variances since there are no packers in the wells and the economics will not allow us to work the wells over. The variances will be based on a pair of temperature surveys before and after injection. There are no fresh water aquifers at risk and the gas reservoirs in this area of the field are either depleted or not at risk due to their location. Even if there were gas reserves in the immediate area, they would be protected through close monitoring of our injection operations which will recognize any casing/well failures. Below is a list of the conversions: B-7, B-16 and B-17 B-15RD and B-27 should pass conventional MITs. will require variances. This program has been initiated and we should be ready for injection around the end of November. This is a final effort in the life of the reservoir's main fault block to maximize the recovery of the Tyonek and Hemlock intervals which are currently near the end of their waterflood life. We expect to see response within 12 months and will probably terminate the waterflood operations permanently if no response is recognized. The facilities modifications are nearing completion and pre-injection temperature surveys are being scheduled for all the wells. Once waterflood is active in our current injectors we will run the MIT's on the first three wells, begin injection into the 5 new wells and after 30 days of injection we will rerun the temperature surveys on B-15RD and B-27 to prove casing integrity. Attachments: 10-403 Forms Wellbore Diagrams Structure/Location Map Reactivation Plans Detailed Plan for each well L'~f]fi sto~ Ruff Senior Reservoir Engineer Cook Inlet Waterflood Management Overall Plan for waterflood reactivation on the Baker Platform 1) Repair surface piping, chemical systems, filter systems and pumps. 2) Install new control and metering systems 3) Start up waterflood in B-4, B-12L, and B-23 which are currently approved for injection. 4) Run conventional MIT' s on B-7, B- 16 and B- ! 7. 5) Run temperature surveys on B-7, B-16, B-17, B-15RD and B-27. 6) Begin injection in all new wells (temporary permission to inject required on B-15RD and B-27). 7) After 30 days, rerun temperature surveys on B-15RD and B-27. 8) Obtain Variance on B-15RD and B-27 based on temperature survey results. 9) Monthly Reporting of daily monitoring on B-12, B-15RD and B-27 with reports sent to AOGCC. 10)Circulate inhibited fluid after waterflood response is recognized. 11)Shut-in operations if no response is seen after 12 months. 12)Renew Variances on B-12, B-15RD and B-27 every other year. B-7 Plan 1) Hookup permanent or temporary injection equipment. 2) Circulate out all power-oil with waterflood water, close both sliding sleeves, gauge tbg and tag bottom. 3) Run conventional MIT and obtain final approval to inject. 4) Hookup permanent injection metering and controls. 5) Inject into the Tyonek A-Zone to support B-6 production B-16 Plan 1) Hookup permanent or temporary injection equipment. 2) Circulate waterflood water, close sliding sleeve, gauge tbg and tag bottom. 3) Run conventional MIT. 4) Obtain approval of MIT. 5) Hookup permanent injection metering and controls. 6) Inject into the Tyonek F-Zone to support B-l 1 and B-13 production. 7) If extra platform capacity exists after the full expansion is completed: Add tbg punch to allow injection into the BCD zone. Add perforations into the Tyonek A-Zone. B-17 Plan 1) Hookup permanent or temporary injection equipment. 2) Circulate out all power-oil with waterflood water and close sliding sleeve #5. 3) Tag isolation disk at 5955 MD and make sure sliding sleeves #7 & 8 are open 4) Run conventional MIT and obtain final approval to inject. 5) Hookup permanent injection metering and controls. 6) Inject into the Tyonek A-Zone to support B-5 and B-6 production B-15RD Plan 1) Run pre-injection temperature survey for baseline data, gauge tbg, and tag cement plug. 2) Hookup permanent or temporary injection equipment. 3) Circulate out all power-oil with waterflood water. 4) Verify temporary permission to inject has been granted. 5) Inject for 30 days into the Tyonek A-F zones. 6) Shut-in for 12 hours and re-run temperature survey. 7) Analyze temperature surveys to prove casing integrity. 8) Obtain variance based on temperature surveys. 9) Hookup permanent injection metering and controls. 10) Inject into the Tyonek A-F zones to support B-6 and B-11 production B-27 Plan 1) Run pre-injection temperature survey for baseline data, gauge tbg and tag drillable bridge-plug. 2) Hookup permanent or temporary injection equipment. 3) Circulate out all power-oil with waterflood water. 4) Verify temporary permission to inject has been granted. 5) Inject for 30 days into the Tyonek A-D zones. 6) Shut-in for 12 hours and re-run temperature survey. 7) Analyze temperature surveys to prove casing integrity. 8) Obtain variance based on temperature surveys. 9) Hookup permanent injection metering and controls. 10) Inject into the Tyonek A-D zones to support B-5 and B-28 production ALASKA OIL AND GAS CONSERVATION COMMISSION PETROLEUM WELL RECORD - Commission use only - 05/08/98 NUMBER N-UMBER NAME NUMBER SRT NUMBER CODE 27 215 ADL0017595 22228 83-0116-0 7332036800 MGS ST 17595 OPER OPEP~ATOR GEOLOGIC CODE I NAME CODEI /d:~.EA HORE CMP 145000 UNION OIL CO OF CALIFORNIA 820 COOK INLET BASIN OFF FLDPOL FIELD AND POOL MULTIPLE POOLS 524114 MIDDLE GROUND SHOAL, E F AND G 524112 524110 000000 000000 000000 +- + II/NIT UNIT CODE I NAME + ELEVATIONS I DEPTHS I COD I ........ ......... ~_~___ _~_v_~__ ,,s~.l___ + FEET DIR FEET DIR SEC TWP RNG MER FEET DIR FEET DIR SEC .......................................... 1985 N 0584 W 31 09N 012W S 4112 S 1982 W 30 09N 012W +- I ..... ..... ~ ~ 83 13235 84 136 CLASSISTATUS CLASS STATUS CLASS STATUS SAMPL MUD SUR OTHER TST ACCTG DEV i-OIL DEV i-OIL DEV C0-O2 NO NO RCV NO 54001 + + 07/26/83 07/26/83 09/19/83 12/15/84 11/30/92 10/06/95 ALASKA INDIVIDUAL WELL PRODUCTION AS OF 05/08/98 WELL-NAME: MGS ST 17595 27 FIELD/POOL: MIDDLE GROUND SHOAL, A API: 733-20368-00 LEASE: ADL0017595 OPERATOR: LINION OIL CO OF CALIFORNIA SALES CD - 54 ACCT GRP - 001 FINAL STATUS: DEV i-OIL CURRENT STATUS: DEV C0-02 ** OIL PRODUCTION ** 1993 JAN METH DAYS OIL WTR GAS 1993 TOTALS OIL FEB MAR APR MAY JUN JVJL AUG SEP OCT NOV DEC HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP 31 30 31 ' 30 31 31 30 31 30 31 190 2 , 811 2,670 2,012 1,729 2,514 2,122 1,241 1,697 2 , 201 24,090 14,744 12,489 18,812 6,211 7,174 9,589 7,018 6,440 6,316 466 1,529 1,373 2,524 1,010 723 590 738 432 795 19,187 WATER 112,883 GAS 10,180 CUM OIL 19,187 CUM WATER 112,883 CUM GAS 10,180 1994 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP DAYS 31 28 31 30 31 30 31 31 30 22 29 31 OIL 3,142 1,063 80 184 916 1,635 1,701 1,480 1,001 688 1,121 1,578 WTR 6,188 9,435 8,669 7,717 10,174 9,280 9,982 8,636 8,308 2,732 10,353 6,237 GAS 646 595 493 451 207 240 369 1,410 827 776 349 9,093 1994 TOTALS OIL 14,589 WATER 97,711 GAS 15,456 CUM OIL 33,776 CUM WATER 210,594 CUM GAS 25,636 1995 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH HYD PUMP HYD PUMP HYD PUMP HYD PUMP SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN DAYS 31 28 14 13 OIL 909 427 200 115 WTR 3,735 5,005 2,461 2,907 GAS 4,700 777 294 190 1995 TOTALS OIL 1,651 WATER 14,108 GAS 5,961 CUM OIL 35,427 CUM WATER 224,702 CUM GAS 31,597 1996 JAN FEB MILR APR MAY JUN JUL AUG SEP OCT NOV DEC METH SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN DAYS OIL WTR GAS 1996 TOTALS OIL WATER GAS CUM OIL 35,427 CUM WATER 224,702 CUM GAS 31,597 1997 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN DAYS OIL WTR GAS 1997 TOTALS OIL WATER GAS CUM OIL 35,427 CUM WATER 224,702 CUM GAS 31,597 1998 JAN FEB M_AR METH SHUT-IN SHUT-IN SHUT-IN DAYS OIL WTR GAS 1998 TOTALS OIL WATER APR MAY JUN JUL AUG SEP OCT NOV DEC GAS CUM OIL 35,427 CUM WATER 224,702 CUM GAS 31,597 FIELD/POOL: MIDDLE GROUND SHOAL, B C AND D SALES CD - 54 ACCT GRP - 001 FINAL STATUS: DEV I-OIL CURRENT STATUS: DEV C0-O2 ** OIL PRODUCTION ** ALASKA INDIVIDUAL'WELL PRODUCTION AS OF 05/08/98 1987 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH HYD PUMP DAYS 31 OIL 21,604 WTR 27,218 GAS 14,065 1987 TOTALS OIL 21,604 WATER 27,218 GAS 14,065 CUM OIL 21,604 CUM WATER 27,218 CUM GAS 14,065 FEB MAR APR MAY JUN JUL AUG SEP OCT NOV 1988 JAN DEC METH HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP DAYS 31 29 30 29 31 30 30 31 30 30 30 31 OIL 20,668 19,389 20,165 14,436 17,187 19,246 17,971 17,662 14,096 13,929 13,409 13,518 WTR 22,573 23,362 20,686 21,816 24,112 9,913 4,994 8,912 7,721 8,325 7,222 7,765 GAS 12,057 11,049 7,832 8,970 11,178 10,456 8,676 12,370 9,644 10,040 10,040 10,375 1988 TOTALS OIL 201,676 WATER 167,401 GAS 122,687 CUM OIL 223,280 CUM WATER 194,619 CUM GAS 136,752 1989 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV ~DEC METH HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP DAYS 30 27 31 30 31 30 31 31 30 31 30 31 OIL 10,191 9,107 8,987 7,865 7,678 7,301 8,499 6,385 5,859 5,362 6,414 6,865 WTR 7,070 6,238 7,935 7,135 7,307 6,810 7,506 7,351 7,359 8,076 6,403 5,567 GAS 8,615 7,795 8,478 6,170 4,613 6,169 6,395 6,848 6,626 8,120 8,664 8,339 1989 TOTALS OIL 90,513 WATER 84,757 GAS 86,832 CUM OIL 313,793 CUM WATER 279,376 CUM GAS 223,584 1990 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP DAYS 31 28 30 30 31 29 31 31 30 31 30 21 OIL 6,030 6,297 5,933 6,412 4,896 4,010 4,052 3,855 2,572 3,476 2,429 562 WTR 7,037 6,791 10,424 6,496 6,275 6,356 4,086 4,345 6,532 6,869 4,314 1,243 GAS. 10,755 9,774 9,239 8,948 9,068 5,919 4,725 4,664 1,883 1,783 1,252 500 1990 TOTALS OIL 50,524 WATER 70,768 GAS 68,510 CUM OIL 364,317 CUM WATER 350,144 CUM GAS 292,094 1991 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH SHUT-IN HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP DAYS 4 30 30 30 30 31 31 30 31 30 OIL 1,184 3,485 4,483 2,416 3,540 2,734 2,468 2,681 3,050 WTR 1,064 6,797 6,258 7,945 5,203 7,884 5,971 5,961 6,742 5,256 GAS 252 864 1,564 2,307 1,780 336 915 2,405 2,152 1991 TOTALS OIL 28,278 WATER 63,972 GAS 14,054 CUM OIL 392,595 CUM WATER 414,116 CUM GAS 25 2,237 4,891 1,479 306,148 1992 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP DAYS 28 16 31 30 31 30 31 31 30 31 30 31 OIL 2,380 1,569 3,371 2,806 2,588 2,802 2,684 2,502 2,874 2,746 2,666 2,671 WTR 6,301 3,288 7,331 5,581 4,984 5,377 6,332 6,242 6,666 6,168 6,249 9,043 GAS 740 403 1,800 1,206 1,162 660 1,272 1,344 1,027 1,087 1,488 1,943 1992 TOTALS OIL 31,659 WATER 73,562 GAS 14,132 CUM OIL 424,254 CUM WATER 487,678 CUM GAS 320,280 1993 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP DAYS 31 22 31 30 31 30 31 31 30 31 30 31 OIL 1,934 664 48 703 668 503 432 628 531 310 424 550 WTR 8,846 13,470 6,022 3,686 3,122 4,703 1,553 1,793 2,397 1,754 1,610 1,579 GAS 3,528 925 117 382 343 631 252 181 147 184 108 199 1993 TOTALS OIL 7,395 WATER 50,535 GAS 6,997 CUM OIL 431,649 CUM WATER 538,213 CUM GAS 327,277 ALASKA INDIVIDUAL WELL PRODUCTION AS OF 05/08/98 1994 J/LN METH HYD PUMP DAYS 31 OIL 785 WTR 1,547 GAS 161 1994 TOTAJ~S OIL FEB MAR APR MAY J-U-N JUL HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP 28 31 30 31 30 31 266 20 46 229 409 425 2,359 2,167 1,929 2,543 2,320 2,496 149 123 113 52 60 92 3,646 WATER 24,427 GAS 3,864 CUM OIL 1995 JAN METH HYD PUMP DAYS 31 OIL 227 WTR 934 GAS 1,175 1995 TOTALS OIL FEB M3LR APR HYD PUMP HYD PUMP HYD PUMP 28 14 13 107 50 29 1,251 615 727 194 74 48 413 WATER 3,527 1996 JAN METH SHUT-IN DAYS OIL WTR GAS 1996 TOTALS OIL FEB MAR APR SHUT-IN SHUT-IN SHUT-IN WATER 1997 JAN METH SHUT-IN DAYS OIL WTR GAS 1997 TOTALS OIL FEB MAR APR SHUT-IN SHUT-IN SHUT-IN WATER 1998 JAN METH SHUT-IN DAYS OIL WTR GAS 1998 TOTALS OIL FEB MAR APR SHUT-IN SHUT-IN WATER FIELD/POOL: MIDDLE GROUND SHOAL, E F AND G 1984 JAN METH DAYS OIL WTR GAS 1984 TOTALS FEB MAR APR OIL 933 WATER MAY JUN JUL SHUT- IN SHUT- IN SHUT - IN GAS 1,491 CUM OIL MAY JUN JUL SHUT- IN SHUT - IN SHUT- IN GAS CUM OIL MAY JUN JUL SHUT-IN SHUT-IN. SHUT-IN GAS CUM OIL MAY JUN JUL GAS CUM OIL SALES CD - 54 ACCT GRP - 001 ** OIL PRODUCTION ** MAY JUN JUL GAS 442 CUM OIL AUG SEP OCT NOV DEC HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP 31 30 22 29 31 370 250 172 280 394 2 , 159 2 , 077 683 2 , 588 1,559 353 207 194 87 2,273 435,295 CUM WATER 562,640 CUM GAS 331,141 AUG SEP OCT NOV DEC SHUT-IN SHUT-IN SHUT-IN SIqLVf-IN SHUT-IN 435,708 CUM WATER 566,167 CUM GAS 332,632 AUG SEP OCT NOV DEC SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN 435,708 CUM WATER 566,167 CUM GAS 332,632 AUG SEP OCT NOV DEC SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN 435,708 CUM WATER 566,167 CUM GAS 332,632 AUG SEP OCT NOV DEC 435,708 CUM WATER 566,167 CUM GAS 332,632 FINAL STATUS: DEV i-OIL CURRENT STATUS: DEV C0-02 AUG SEP OCT NOV DEC HYD PUMP 28 933 933 CUM WATER CUM GAS 442 442 ~ DJ=ASKA INDIVIDUAL WELL PRODUCTION AS OF 05/08/98 1985 JAi~ FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP DAYS 29 28 31 28 31 30 31 31 30 30 30 31 OIL 760 1,266 1,713 1,795 2,635 2,222 2,799 2,388 2,422 3,022 2,246 2,192 WTR 163 72 74 591 36 67 GAS 380 562 765 920 1,368 1,182 1,310 1,168 1,184 1,590 1,133 1,071 1985 TOTALS OIL 25,460 WATER 1,003 GAS 12,633 CUM OIL 26,393 CUM WATER 1,003 CUM GAS 13,075 1986 J/LN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP DAYS 31 28 31 30 31 30 31 31 30 31 30 31 OIL 2,003 1,739 1,886 1,668 1,516 1,105 1,450 745 606 755 2,154 2,237 WTR GAS 916 504 620 2,430 1,078 877 1,085 1,519 1,663 1,524 1,657 1,718 1986 TOTALS OIL 17,864 WATER 1 GAS 15,591 CUM OIL 44,257 CUM WATER 1,004 CUM GAS 28,666 1987 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV METH HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP DAYS 31 28 31 30 31 30 31 31 30 31 25 OIL 484 354 261 241 1,486 472 1,085 1,067 910 1,289 922 WTR 1 1 GAS 1,451 2,021 2,031 1,656 2,398 1,994 3,024 1,435 1,516 1,424 1,364 1987 TOTALS OIL 8,571 WATER 2 GAS 20,314 CUM OIL 52,828 CUM WATER 1,006 CUM GAS DEC 48,980 1988 JAN METH ~DAYS OIL WTR GAS 1988 TOTALS OIL FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN WATER GAS CUM OIL 52,828 CUM WATER 1,006 CUM GAS 48,980 MEMORAND vl State Alaska Alaska Oil and Gas Conservation Commission TO: David John, s~n, Chairmaff'~P~ ~~.~ THRU: pB ,.~i.r~u; ~ drv~. ~ Iol ~. \~. ~U~) FlEE NO: FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector DATE: April 9, 1994 9VEJDHBD.DOC No Flow Verification Wells #D-20,12,27,28,&25 Marathon Dolly Varden platform Middle Ground Shoal Field Friday, April 8, 1994: I traveled to Marathon's Dolly Varden platform in the Middle Ground Shoal field of Cook Inlet to verify the No Flow status of five wells. When I arrived the wells had already had their gas lift shut in and the tubing flowed down to the group separator, These were then flowed to the well clean system which has approximately .5 psi back pressure on it. The wells tubing was then routed to open top containers with water in them. All wells bled only gas and died off quickly with the exception of well #D-25 which kept flowing gas and would build up to 160 psi rather quickly, this may have been residual gas in the annulus coming through a leaky gas lift valve. The platform needed this well back for production and we did not attempt any further tests on other wells. Recommendations: Wells # D-20, D-12, D-27, and, D-28 exhibited a inability to flow from the formation without the assistance of artificial lift and met the criteria for No Flow status. Well # D-25 would not die off and should be maintained as a flowing well. Summary: I verified the no flow status of 4 wells on Marathon's Dolly Varden platform. cc: Don Lacour (Production Superintendent) .~--. STATE OF ALASKA ----.. ALASK, IL AND GAS CONSERVATION C£ JllSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate _ Plugging __ Perforate X Pull tubing Alter casing Repair well Pull tubing X Other 6. Datum elevation (DF or 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 196247, Anchorage, AK 99519-6247 4. Location of well at surface Leg #2, Conductor #5 1985' FNL & 584' Fwl Sec 31, T9N, R12W, SM At top of productive interval 1878' FSL & 1737' FWL Sec 30, T9N, R12W, SM At effective depth 3640' FSL & 1921' FWL Sec 30, T9N, R12W, SM At total depth 4112' FSL & 1982' FWL Sec 30, T9N, R12W, SM 5. Top of"A" zone 7105' MD 9950' MD (7691' TVD) 11600' MD (9258' TVD) Type of Well: Exploratory __ 75' RKB above MLW feet Stmfigraphic __ 7. Unit or Property name se~ice MGS STATE 17595 -- 8. Well number Well No. 27 9. Permit number/approval number 83-116/93-013 10. APl number 50-133-20368 11. Field/Pool Middle Ground Shoal 12. Present well condition summary Total depth: measured true vertical 11,600' 9,258' feet Plugs (measured) feet Effective depth: measured 9,950' true vertical 7,691' feet Junk (measured) feet Casing Length Size Structural Conductor Surface 3407' 13-3/8" Intermediate 8844' 9-5/8" Production Liner 3002' 7" Perforation depth: measured Cemented Measured depth True vertical depth 3070 SXS 3407' 2954' 1400 SXS 8844' 6763' 925 SXS 8590'- 11592' 6568'-9250' See attached sheet true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) LS: 3-1/2", 9.2#, L-80, TDS @ 7051' SS: 3-1/2", 9.2#, L-80, TDS @ 7016' None RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) See attached history Treatment description including volumes used and final pressure APR - 5 i99~, Alaska OJJ & Gas Cons. Anchorage 14. Prior to well operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X- 16. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the for~goin,,g is tru~j~n~ cRrre~ct~tp.the best of my knowledge. Signed G. RusselSchmidt ~ -- ' Title Reqional Drilling Manager Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE BAKER PLATFORM BA #27 BAKER PLATFORM BA #27 9950' ETD DAY I (02/09/93) 9-5/8" C @ 7565' 7" L F/8590'-11127' 452 PSI RU SERVICE LINES TO BA #27. KILL WELL W/5% KCL WTR. RIG DN MANIFOLD, SET BPV(S). NU BOPE & TEST SAME. CIRC WELL (LS X ANNULUS) UNTIL CLEAN. MU LANDING JTS & UNSEAT TBG HGR. CBU. BA #27 9950' ETD DAY 2 (02/10/93) 9-5/8" C @ 7565' 7"L F/8590'-11127' 452 PSI POOH, LAY DN __.+ 625' F/EACH TBG STRING. LAND HGR & SECURE SAME. REMOVE LANDING JTS & SET BPV. ND BOPE. INSTALL PROD TREE & TEST SAME TO 5000 PSI, OK. PULL BPV'S. PREP & SKID RIG F/LEG #2 TO LEG #4. RIG RELEASED 2400 HRS. Alaska Oil & Gas Coils. Anchorage 1 15-5/8" 54.5, ~ 61 & 68# @5407' TOP OF LINER @ 8590' 9-5/8-40, 45.5, // 47 & 55.5// @ 7565' PBTD @ 110707 / 7" 29 & 55// @ 11127' 1 A KOBE B HA TUBING DETAIL I L ONG STRING (POWER FLUID) 1) CIW HANGER (BU'Fr-DOWN, EUE 8RD-UP) @ 50.25' 2) 5-1/2 BUTI- PIN(UP) x TBS PIN(DOWN) X-OVER @ 5 1.58' L5) 5-1/2" 9.2# N-80 TBO, TDS W/ SP CE CPLOS 4) 5-1/2 TDS BOX x 5-1/2 EU 8RD PIN X-OVER @ 7017' 5) KOBE 5" MODEL "B" BHA @ 7059' SHORT STRING (PRODUCTION) A) ClW HANGER (DUI-r-DOWN, EUE 8RD-UP) @ 50.25' B) 5-1/2 BU-B- PIN(UP) x TDS PIN(DOWN) X-OVER @ 5 1.08' C) 5-1/2" 9.2# N-80 TBO, TBS W/ SP CL CPLGS D) 5-1/2 TDS BOX x 2-,3/8 EU 8RD PIN X-OVER @ 7006' E) 2-5/8" 4.6# N-80 EU 8RD PUP @ 7016' TAIL ASSEMBLY 6) 3-1/2" EU 8RD BOX x 5-1/2" BUTT X-OVER @ 704 1' 7) 5-1/2" 9.2# N-80 BUTT PUP (10') 8) 5-1/2" BUTT WlRELINE RE-ENTRY GUIDE @ 705 1' "A" ZONE PERFORATIONS 7105'-7146' 7252'-7550' "B" Z -- 7476 7668 7788 "C" Z 7958 8072 8180 8274 -- "D" Z 8476 ONE PERFORATIONS '- 7578' SQZD '- 7765' '- 7875' ONE PERFORATIONS '- 7995' '- 8165' '- 8262' '- 8528' ONE PERFORATIONS '- 8511' DRILLABLE BP @ 9950' "G" ZONE PERFORATIONS 9968' - 10052' 10952'- 10958' 10954'- 10960' 10974'- 10980' RECEIVED APR - 5 ~o_~ Alaska, Oil & 6as Oons. 6orr~rf Anchorage UNION OIL ADL 17595 WELL NO. 27 COMPLETION SCHEMATIC COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN' [)AC SCALE: NONE DATE: 02-22-9.3 MGS 17595 #27 PERFORATION RECORD 5485-5517 A OPEN7105-7146 A OPEN 7252- 7350 5598- 5674 B- 1 SQUEEZED 7476-7578 5845-5847 B- 2 OPEN 7668- 7765 5914- 5984 B- 3 OPEN 7788- 7875 6000-6062 C- 1 OPEN 7938-7993 6106-6145 C-2 OPEN 8072- 8163 6200- 6266 C- 3 OPEN 8180- 8262 6277- 6335 C - 4 OPEN 8274- 8328 6340- 6381 D- 1 OPEN 8476-8511 6487-6513 G- 2 ISOLATED BY CMT 9968-10052 7707- 7781 RET @ 9950' G-3 SQUEEZED 10758-10931 8431-8598 ISOLATED BY CMT 10932-10938 8599- 8605 RET @ 9950' SQUEEZED 10939-10953 8606-8619 ISOLATED BY CMT 10954-10960 8620-8626 RET @ 9950' SQUEEZED 10961 - 10973 8627-8639 ISOLATED BY CMT 10974-10980 8640-8646 RET @ 9950' SQUEEZED 10981 - 11114 8647-8778 UNOCAL TUBULAR DETAIL WELL #: Baker Platform, Well# BA--27 MGS 17595 PAGE I o[ 1 DATE: February 10, 1993 AFE NO.: 731406 STRING: Long String; 3-1/2~, 9.2#, bi-80, SC TDS Tubing FOREMAN: 1 Wireline Re-entry Guide 0.76 7050.58 7051.34 1 Pup Joint; 3-1f2", 9.2#, N-80, SC TDS 9.4 7041.18 7050.58 1 Cross Over; 3-1/2" Buttress x 3-1/2" EUE 1.72 7039.46 7041.18 1 3" KOBE BHE, Model "B" 22.63 7016.83 7039.46 1 Cross Over; 3-1/2" EUE x 3-1/2" TDS 2.42 7014.41 7016.83 1 Pup Joint; 3-1/2", 9.2#, N-80, SC TDS 10.04 7004.37 7014.41 3 Joints 3-1~', 9.2#, N-80, SC TDS Tubing 93.6 6910.77 7004.37 1 Pup Joint; 3-1/2", 9~2#, N-80, SC TDS 8.05 6902.72 6910.77 220 Joints 3-1f2", 9.2#, N-80, SC TDS Tubing 6871.14 31.58 6902.72 1 Cross Over; 3-1/Z' Buttress x 3-1/Z' TDS 0.5 31.08 31.58 1 CIW Tubing Hanger 0.83 30.25 31.08 KB 30.25 0 30.25 0 0 :::: :::::: :::: :: ::: :::::: :::::: :: :::::: :: :: :: ::: :: :: ::::: :: ::::::::: :::: :: ::::: :: :: :::: ::::: :::::: ::: :::: ::::: :::::::::: ::::::::: :::::::: :: :: :::: ::: :::: :: :: :: :::::: :::: ::::::: :: :::: :: :::: :: :: :: :::: :: :::: :::: :: :::::::: :::: :::::::::: :::::::::: :::::::::::::5: :::::::::::::::::::::::: ::U:::U:¥ :-:.:::: i::ii ::i ii::i::i::ii i:: i:: ::! ::::i:::.i::iii:-:: ii :.i:.i:::: :.::i ::::i!:.i::::i il ?.::i ~ ~!~::.~::~:. ~ ~i ~~: ~ :::::::::::::::::::::::::: iii ii il;!i!iii !ii ii::::i:. ::iii ii i:.!iii!i!i!i!!i ! iii::ii o .:-:.:-:-:+:-:.:.:-:-::: :-:-: :.:.:.:.:.:.:.:.:.:.:.:.:.-. :- . ~ .- ..: .- ~...-.-.: :.- ... ,.. -_- .......-.... :..:.-.-......: .- ...............:_....:.: :. ~ - ..~ . .~: :-: :.:. :.:.:.:.:.:.:.:: ::+: :.:.: :.:.:.:.:: :::::::::::::::::::::::::::::::~::~::::::::::::::::::::::::::::~:::::~::::::::::::::::::::::::::::::::::::::::::::5:::::::-::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::U:¥:U:::¥:U:::¥:::U:Uf 0 0 0 0 0 0 0 0 0 Top Of KOBE Cavity Is At 7,017' 0 626.22' Laid Down F/Long String 0 624.32' Laid Down F/Short String 0 Bottom Depths Taken F/Tbg. Detail Dated 03/08/91 0 Long String Capacity to Cavity is 61 BBLS 0 Short String Capacity to Cavity is 61 BBLS 0 0 0 0 K L IV L)' 0 0 CopxTo: W¢llFiles 02/'25/93 ~pf~ -,~ t.qn3 0 Copy To: L. Lohoe£er ~ .~ .... Copy To: Rig Anchor tga o Copy To: C. Fauikner 0 0 0 WELL #: DA TE: STRING: UNOCAL TUBULAR DETAIL Baker Platform, Wcli~ BA--27 MGS 17595 PAGE 1 of Februsty 10, 1993 AFE NO.: Short Striog; 3-1f2~, 9.2~, N-80, SC TDS Tubiag FOREMAN: 731406 1 Pup Joint; 3-1f2", 9.2#, N-80, SC TDS 10.07 7006.09 7016.16 1 Cross Over; 3-1/2' TDS x 2-3/8" EUE 0.74 7005.35 7006.09 3 Joints 3-1/2', 9.2#, N-80, SC TDS Tubing 93.5 6911.85 7005.35 1 Pup Joint; 3-1/2", 9.2#, N-80, SC TDS 10.04 6901.81 6911.85 220 Joints 3-1/2", 9.2#, N-80, SC TDS Tubing 6871.2 30.61 6901.81 Tension {Long String} -1.9 32.51 30.61 1 Cross Over; 3-1/2' Buttress x 3-1/2' TDS 1.43 31.08 32.51 1 CIW Tubing Hanger 0.83 30.25 31.08 KB 30.25 0 30.25 0 0 0 0 0 0 0 0 0 0 Top of KOBE is at 7017' 0 626.22' Laid Down F/Long String 0 624.32' Laid Down F/Short String 0 Bottom Depths Taken F/Tbg Detail Dated 03/08/91 0 Long String Capacity to Cavity is 61 BBLS 0 Short String Capacity to Cavity is 61 BBLS 0 0 0 0 0 0 0 0 0 0 Copy To: Well Files 02/25/93 0 Copy To: Rig -~ ~-' .... G~S COi~S, G0t'ill~_~iS~'.,' 0 Copy To: C. Faulkner ......... 0 0 ----- STATE OF ALASKA ALASKA LAND GAS CONSERVATION CC, ;ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon __ Suspend __ Alter casing__ Repair well __ Change approved program Operations shutdown __ Re-enter suspended w~J~.., Plugging __ Time extension Pull tubing __ Variance Pe-dorate X (~e~ 5. Type of Well:Development ~-- 6.-D-atum elovMfe'h~)~r KB) 101 RKB MLW -~,~ feet Exploratory 7. Unit or Property name 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 196247, Anchorage, AK 99519-6247 4. Location of well at surface Leg #2, Conductor #5 1985' FNL, 584" FWL Sec 31, T9N, R12W, S.M. At top of productive interval 2238' FNL, 1790' FWL, Sec 30, T9N, R12W, S.M. Top of "B" zone 7678' MD At effective depth 3640' FSL, 1921' FWL Sec 30, T9N, R12W, S.M. 9950' MD (7691' TVD) At total depth 4112" FSL, 1982' FWL Sec 30, T9N, R12W, S.M. 11600' MD (9258' TVD) Sbafigraphic Service MGS STATE 17595 -- 8. Well number Well No. 27 9. Permit number 83-0116-0 10. APl number 50 -733-20368 -00 11. Field/Pool Middle Ground Shoal 12. Present well condition summary Total depth: measured true vertical 11600' feet Plugs (measured) 9258' feet Effective depth: measured 9950' true vertical 7691' feet 'Junk (measured) feet Casing Length Size Structural Conductor Surface 3407' 13-3/8" Intermediate 8844' 9-5/8" Production Liner 3002' 7" Perforation depth: measured See attached sheet true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth 3070 SXS 3407' 2954' 1400 SXS 8844' 6763' 925 SXS 8590'- 11592' 6568'-9250' LS: 3-1/2", 9,2#, L-80, TDS @ 7677' SS: 3-1/2", 9,2#, L-80, TDS @ 7642'A!as!( NONE 13. Attachments Description summary of proposal X Detailed operations program X BOP sketch X 14. Estimated date for commencing operation 115. 16. If proposal was verbally approved I Oil X Gas __ Name of approver Date approved Service 17.1 herel~e~ th.a~e .~ue and correct to the best of my knowledge. · . Status of well classification as: Suspended Signed (3. RusselISchmidt Title Regional Drilling Manager FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug Integrity __ BOP Test Mechanical Integrity Test Approved by the order of the Commission Form 10-403 Rev 06/15/88 Location clearance Subsequent form required 10- 5/~' Approval No. Commi io.er Da ,, / SUBMIT IN TRIPLICATE ZONE MGS 17595 #27 Perforat±on Record CONDITION MEASURED DEPTH TRUE VERTICAL DEPTH B-1 B-2 B-3 C-1 C-2 C-3 C-4 D-1 SQUEEZED 7476-7578 5845-5847 OPEN 7668-7765 5914-5984 OPEN 7788-7875 6000-6062 OPEN 7938-7993 6106-6145 OPEN 8072-8163 6200-6266 OPEN 8180-8262 6277-6335 OPEN 8274-8328 6343-6381 OPEN 8476-8511 6487-6513 G-2 G-3 ISOLATED BY 9968-10052 CMT RET @ 9950' SQUEEZED 10758-10931 ISOLATED BY 10932-10938 CMT RET @ 9950' SQUEEZED 10939-10953 ISOLATED BY 10954-10960 CMT RET @ 9950' SQUEEZED 10961-10973 ISOLATED BY 10974-10980 CMT RET @ 9950' SQUEEZED 10981-11114 7707-7781 8431-8598 8599-8605 8606-8619 8620-8626 8627-8639 8640-8646 8647-8778 RECEIVED Aias!<a Oil & Ga~ Cei-~s. Corr~missior~ Anchorag~ MGS 17595 BAKER #27 PROPOSED WORKOVER JANUARY 6, 1993 PROCEDURE 1. MOVE RIG OVER MGS 17595 #27, LEG #2, SLOT #5. 2. KILL WELL WITH COMPLETION FLUID (5% KCL FLUID) 3. INSTALL BPV'S, NIPPLE DOWN TREE, NIPPLE UP BOPE. 4. PULL DUAL HANGERS LOOSE, LAY DOWN 500' OF TUBING ON EACH STRING TO RAISE THE BHA TAIL TO 7200'. RELAND THE COMPLETION. 5. INSTALL BPV'S, NIPPLE DOWN BOPE. NIPPLE UP TREE. 6. WIRELINE PERFORATE (THRU TUBING) 139' OF "A" ZONE INTERVALS: 7105'-7146' DIL (41') 7252 '-7350' DIL (98') DAYS ~/4 1/2 1/2 1/2 4 DAYS NOTE: DRILLING RIG WILL NOT BE DIRECTLY INVOLVED WITH PERFORATION OPERATION FOR COST REASONS. RICE,ViD ; ,~' .J ~.~ 15-3/8" 54.5,/1 61 & 68# @3407' TOP OF LINER @ 8590' 9-5/8" 40, 47.5, // 47 a 53.5# @ 7565' PBTD @ 11070 7" 29 & 55# @ 11127' 1 A 5 KOBE BHA TUBING DETAIL LONG STRING (POWER FLUID) 1) CIW HANGER (BUTr-DOWN, EUE 8RD-UP) @ 50.25' 2) 3-1/2 BUTt PIN(UP) x TDS PIN(DOWN) X-OVER @ 31.08' L3) 3-1/2" 9.2# N-80 TBG, TDS W/ SP CE CPLGS 4) 5-1/2 TDS BOX x 3-1/2 EU SRD PIN X-OVER @ 7641' 5) KOBE 3" MODEL "B" BHA @ 7643' SHORT STRING (PRODUCTION) A) CIW HANGER (BUTT-DOWN, EUE 8RD-UP) @ 50.25' B) 3-1/2 BuTr PIN(UP) x TDS PIN(DOWN) X-OVER @ 31.08' C) 3-1/2" 9.2# N-80 TBG, TDS W/ SP CE CPLGS D) 3-1/2 TDS BOX x 2-3/8 EU 8RD PIN X-OVER @ 7651' E) 2-3/8" 4.6# N-80 EU 8RD PUP @ 7632' TAIL ASSEMBLY 6) 5-1/2" EU 8RD BOX x 3-1/2" BUT[ X-OVER @ 7666' 7) 3-1/2" 9.2# N-80 glJ]-r PUP (10') 8) 3-1/2" BUTT WlRELINE RE-ENTRY GUIDE @ 7677' "B" ZONE PERFORATIONS 7476'- 7578' SQZD 7668'- 7765' 7788'- 7875' "C" ZONE PERFORATIONS 7958'- 7993' 8072'- 8165' 8180'- 8262' 8274'- 8528' "D" ZONE PERFORATIONS 8476'- 8511' DRILLABLE BP @ 9950' "G" ZONE PERFORATIONS 9968' - 10052' 10952'- 10958' 10954'- 10960' 10974'- 10980' A.rlchor2q~ UNION ADL 17595 WELL NO. 27 COMPLETION SCHEMATIC OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN' DAC SCALE: NONE DATE' 11-18-92 ~3-~/8" 54.5, 61 & 68# @3407' TOP OF LINER @ 8590' 9-5/8" 40, 4,5.5, Z 47 & 5,5.5/:/ @ 7565' PBTD @ 11070' 7" 29 & 55# @ 11127' 1 A 5 KOBE BHA TUBING DETAIL l L ONG STRING (POWER FLUID) 1) CIW HANOER (BUTT-DOWN, EUE 8RD-UP) 2) 3-1/2 BU'FF PIN(UP) x TBS PIN(DOWN) X-OVER b5) 5-1/2" 9.2# N-80 TBO, TDS W/ SP CL CPLOS 4) 3-1/2 TDS BOX x 5-1/2 EU 8RD PIN X-OVER 5) KOBE 5" MODEL "B" BHA SHORT STRING (PRODUCTION) A) CIW HANGER (BU'I-r-DOWN, EUE 8RD-UP) B) 5-1/2 BU-I-r PIN(UP) x TDS PIN(DOWN) X-OVER C) 5-1/2" 9.2# N-80 TBO, TBS W/ SP CL CPLOS D) ,3-1/2 TDS BOX x 2-5/8 EU 8RD PIN X-OVER E) 2-5/8" 4.6# N-80 EU 8RD PUP TAIL ASSEMBLY 6) 5-1/2" EU 8RD BOX x 5-1/2" BLFFI' X-OVER 7) 5-1/2" 9.2# N-80 BUTT PUP (10') 8) 5-1/2" BLrFI- WlRELINE RE-ENTRY GUIDE "A" ZONE PERFORATIONS 7105'- 7146' 7252'- 7550' "B" ZONE PERFORATIONS 7476'- 7578' SQZD 7668'- 7765' 7788'- 7875' "C" ZONE PERFORATIONS 7958'- 7995' 8O72'- 8165' 8180'- 8262' 8274'- 8528' "D" ZONE PERFORATIONS 8476'- 8511' DRILLABLE BP @ 9950' "O" ZONE PERFORATIONS 9968' - 10052' 10952'- 10958' 10954'- 10960' 10974'- 10980' AJaska Oil & G,qr; Cc'..ns. (;or.w¢i Anchora,ge UNION ADL 17595 WELL NO. 27 PRQPOSED COMPLETION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN' DAC SCALE: NONE DATE: 11-18-92 FILL-UP KILL LINE 135/s"3000 psi PIPE RAMS 135/8"5000 psi BLIND RAMS 135/8"5000 psi [DRILLING[ E~ [-b~[/dTb-~ ~ SPOOL --~ ~a~¢ooo p~~ 4" 5000 psi il II 4" 5000 I [ PIPE RAMS 13 s/d5000 psi CHOKE LINE-- FLOW psi RISER 135/8" 5000 psi Aiaska Oil & COOK INLET PLATFORMS BOPE STACK 13 %" 5000 psi TO 10" CROWN VENT BLOW DOWN I III I I I'I, GAS BUSTER TO CHOKE . PANEL ..... 1 MANUA'L 10" TO SHAKER ~:' SWACO CHOKE ;,7 !.-::, '.::: " ...... NOTE: SWACO CHOKES "";~;';' ~:~ :~':'; ~<:~=~ EACH HYDRAULICALLY ~= .... -' ?'~'; ACTUATED VIA REMOTE. TO BOPE SWACO CHOKE CHOKE MANIFOLD Unocal PLATFORM RIGS 4-1/1¢ & :l-l/0", 5M ~SP ALA,. , OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Pull tubing __ Alter casing __ 2. Name of Operat~ruNOCAL ) ! 5. Type of Well: i of California ! Development Exploratory 3. Address Stratigraphic __ P.O. BOX 196247, AnCh. , AK, 99519 Service 4. Location of well at surface Leg # 2, C6nductor 5 1985· FNL & 584' FWL, Sec 31, T9N, R12W, SM At top of prod~t~inf~al "B" Zone at 7678· MD 2238· FSL & 1790· FWL, Sec 30, T9N, R12W, SM At effective del~h950 ' MD ( 7691 ' TVD ) 3640· FSL & 1921· FWL, Sec 30, T9N, R12W, SM 4Atfntgld~_nthll,600·i.i.2 i~"S'L TMD (9258· TVD) & 1982 ' FWL, Sec 30, T9N, R12W, SM 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical 11,600 9,258 measured true vertical 9,950 7,691 Length Size 3407' 13-3/8 8844· 9-5/8 3002 ' 7" measured Stimulate ~ Plugging ~ Perforate ~ Repair well ~ Pull tubing __ Other __ · feet Plugs (measured) · feet feet Junk (measured) · feet 6. Datum elevation (DF or KB) 101 ' RKB ABOVE MLWaet 7. Unit or Property name MGS STATE 17595 8. Well number Well No. 27 , 9. Perr~i~n._u~]bebJ'~l~j_o.v~ :~LJlrnber 50-- 3-20368 11'Field/F~ddle Ground Sho Cemented Measured depth True vertical depth 3070 sxs 3407' 2954' " 1400 .sxs 9255 SXS 8844' 6763' 8590'-11592' 6568'-9250' true vertical See attached sheet Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) LS: 3-1/2" 9 2# SS: 3-1/2" 9 2# , · , None L-80, TDS at 7677' L-80. TDS at 7642' RECEIVED 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) 7668 ' - 8511 ' Treatment description including volumes used and final pressure 2655 gal 4419 gal Alaska 0il & Gas Cons. ~;ummissiO 7.5% HCL, 20% ~t~r~l~ 7.5%o HCf., 4450 psi Representative Daily Average Production or Injection Data Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations OiI-Bbl Gas-Mcf Water-Bbl 90 35 200 59 32 219 l~.S~usdwellclassificationas: Casing Pressure Tubing Pressure Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~.x~. Gary S. Bus];k __ Si~,ned (,.~ ~. Form 10-404 Rev 06/15/88 (~ ~ Regional Drilling Manager Date SUBMIT IN DUPLICATE DATE 0.3/'03/9% 03/06/91 33/02/91 12/20/~ 12/20/85 PERFORATING RECORD INTERVAL 6022'-6052' 6092'-~t4~' 6160'-6230' 6385'-~438' 6454'-6502' 6518'-6568' 6581'-~07' 6645,5'-6647,5' 6663'-6683' 6700'-6727' 6788'-6800' E.T.D. 6~4~' 6645' 6645' 6645'' 66~Q' 7180' 7180' 718Q: REASON ?RODUCTTON pRODUCTION PRODUCTION pKODUCTION PRODUCTION ~RODUCTTON SOUEEZE .. PRESENT CONDITION ~oz'D W/2oo. sxz ~ OPEN ( GRAV~T~ .PACK 3 OPEN ( GRAVATr:PACK 3 OPEN ( GRAV~T~T- PACK 3 OPEN' ¢ GRA~A~K 3 , OPEN ( GRAVA'n- 'i~ACK ~ OPEN (GRAVI~T. PACK~ SOZ'D W/200 SXS ISOT~ATA'"D BY CMT R~I?~ 6'650 ISOT. ATED' ~Y'CMT~RET.~ 665Q I.qOT.AT~T1 BY CMT RET'~' 665Q · RECEIVED JAN 2 7 3992 Alaska Oil & Was Cons, Commissio,~ Anchorage BAKER ~27 COILED TUBING ACID JOB HISTORY DATE ETD COMMENTS 12/12/91 9501' WLM CIRCULATED THE PUMP OUT OF THE HOLE. RIH WITH SLICKLINE AND RECOVERED THE STANDING VALVE. RIH AND TAGGED FILL AT 9501'. 12/16/91 9501' WLM RIH WITH THE DUMMY PUMP ON SLICKLINE. RIGGED UP COILED TUBING AND THE ACID PUMPS. PRESSURE TESTED THE SURFACE EQUIPMENT TO 5000 PSI. RIH TO 8525'. WASHED FROM 8525'-7675' USING 63 BBLS (2655 GALS) OF 7.5% HCl WITH 20% XYLENE AT 0.75 BBL/MIN AND 10 FPM WHILE TAKING RETURNS TO PRODUCTION. DISPLACED WITH 15 BBLS 3% KC1 AND ALLOWED TO SOAK FOR 2-HRS. LOADED THE COILED TUBING WITH ACID AND RIH TO 8520'. WASHED FORM 8520'-7675' USING 15 BBLS (630 GAL) OF 7.5% HCl. THE COILED TUBING PLUGGED OFF (5200#, .3 BPM). SWITCHED TO 3% KCl AND DISPLACED THE COILED TUBING. POOH AND FOUND THE SWIRL NOZZLE PLUGGED WITH BLACK AND ORANGE PAINT CHIPS. AT THIS POINT A THICK WHITE EMULSION WAS NOTICED IN THE LINES, APPARENTLY IT BREAKS AT 150 DEGREES FAHRENHEIT IN ABOUT AN HOUR. INSTALLED A 100 MESH FILTER IN THE LINE AND TESTED EQUIPMENT TO 5000 PSI. RIH TO 8000' WITH THE COILED TUBING. LOADED THE COILED TUBING WITH 7.5% HCl. USING 27 BBLS (1134 GAL) 7.5% HCl AT 1 BPM AND 20 FPM WASHED FROM 8200'-7675'. RIH TO 8520'. USING 7.5% HC1 AT 0.75 BPM AND A 10FPM RATE WASHED FROM 8520' - 7675' USING 63 BBLS (2655 GAL). THE LAST STAGE WAS TAGGED WITH A RADIOACTIVE TRACER. SQUEEZED 79 BBLS 3% KCl. 12/17/91 9501' WLM POOH AND RIGGED DOWN THE COILED TUBING. RIGGED UP SLICK LINE. RIH AND PULLED THE DUMMY PUMP. RIH WITH THE STANDING VALVE. CIRCULATED THE PUMP TO BOTTOM. RELEASED THE WELL TO PRODUCTION RECEIVED JAN 2 ? t992 Alaska 0il & 6as Cons. Anchorage --' o, A ASKA 0 ii OIL AND GAS CONSERVATION COM MIS..,..3N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Qoera(l:~NOCAL ) ~nion Oll Company of California .3._Addrass ~.U. ~ox 196247, Anch., AK, 99519 Pull tubing __ Variance __ Operation shutdown m Re-enter suspended well __ Plugging ~ Time extension ~ Stimulate ~ Pedorate __ Other __ 5. Type of Well: Development _2~ Exploratory __ Stratigraphic __ Service __ 4. Location of well at sudace Leg #2, Conductor #5 .985' FNL & 584' FWL, Sec 31, T9N, R12W, SM Attopofproo~ei~rV~'B" Zone at 7678' MD 238' FSL & 1790' FWL, Sec 30, T9N, R12W, SM At effective d~j¢50 ' MD ( 7691 ' TVD ) 640' FSL & 1921' FWL, Sec 30, T9N, R12W, SM At total depthl 1,600 ' TMD ( 9258 ' TVD ) 112' FSL & 1982' FWL, Sec 30, T9N, R12W, SM feet Plugs (measured) 12. Present well condition summary Total depth: measured 11,600 ' 61%~u~ ion,(~F,.,qr.~B), ,_ W Z~°rf~R~ ny~5 9 5 8. Well number Well No. 27 9. Permit number 83-116/91-031 10. APl number 50-- '3,.33-20368 11. Field/Pool ~id~d. le. Ground Shoal EIVED Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 3407' 8844' 9,258' 9,950' 7,691' Size feet feet feet 13-3/8" 9-5/8" Junk (measured) Cemented 3070 sxs 4la$1~,Ojl.& Gas Co,s. Commi~io. ' ~clZo_mge' Measured depth ' - True vedical depth 3407' 2954' 1400 SXS 8844' 6763' 3002' 7" 9255 SXS 8590'-11592' measured 6568'-9250' truevertical See attached sheet Tubing (size, grade, and measured depth) LS: 3-1/2", 9.2#, L-80, TDS at 7677' SS: 3-1/2", 9.2#, L-80. TDS at 7642' Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal __ Detailed operations program.If,_ BOP sketch z,_ 14. Estimated date for commencing operation December 8, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas__ Suspended __ Service 17. I hereby certify tha~-t,he forego~ ng is true and correct to the best of my knowledge. ~ ~Z~ 11 ing ManagezDate Sig.ed Gary FO M Conditions of approval: Notify Commission so representat've ay 't ess I Approval No.? Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commissioner ORIGINAL SIGNED BY LONN!E C. Commissioner Date ii '~'7- q I Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE TUBING DETAIL BAKER PLT MGS 17595#27 3/08/91 3-1/2", FROM 9.2~, N-80 TDS TUBING WITH SP CL COUPLINGS LONG STRING TO LENGTH JOINTS DESCRIPTION 7677.56 7676.80 .76 7676.80 7667.40 9.40 PUP 7667.40 7665.68 1.72 7665.68 7643.05 22.63 7643.05 7640.43 2.42 7640.43 7630.59 10.04 PUP 7630.59 7536.99 93.60 3 7536.99 7528.94 8.05 PUP 7528.94 31.58 7497.36 240 31.58 31.08 0.50 31.08 30.25 0.83 30.25 0.00 30.25 FROM 7642.38 7632.31 7631.57 7538.07 7528.03 32.51 31.08 30.25 SHORT STRING WIRELINE REENTRY GUIDE 3-1/2" 9.2# N-80 BUTT PUP 3-1/2" EUE x 3-]_/2" BUTT 3" KOBE BHA, MODEL "B" 3-1/2" TDS x 3-1/2" EUE 3-1/2" 9.2# TDS 3-1/2" 9.2# TDS 3-1/2" 9.2# TDS 3-1/2" 9.2# TDS 3-1/2" BUTT x 3-1/2" TDS CIW TBG HANGER LANDED BELOW ZERO XO X© XO TO LENGTH JOINTS DESCRIPTION 7632.31 7631.57 7538.07 7528.03 32.51 31.08 30.25 0.00 10.07 0.74 93.50 10.04 7495.52 1.43 0.83 30.25 PUP 3 PUP 240 2-3/8" 4.6# N-80 EUE 8RD 3-1/2" TDS x 2-3/8" EUE XO 3-1/2" 9.2# N-80 TDS 3-1/2" 9.2# N-80 TDS 3-1/2" 9.2# N-80 TDS 3-1/2" BUTT x 3-1/2" TDS XO CIW TBG HANGER LANDED BELOW ZERO 1 ~3-3/s" 54.5,//] 6~ & ~8# ~3407' TOP Of LINER @ 8590' 9-5/8" 40, 43.5, Z 47 & 53.5# @ 7565' PBTD @ 11070/ 1 A 5 KOBE BI-IA , , TUBING DETAIL I L ONG STRING (POWER FLUID) 1) OM/ HANGER (BUTt-DOWN, RUE 8RD-UP) · 30.25' 2) 3-1/2 BUTt PIN(UP) x TOS PIN(DOWN) X-OVER · 31.08' r3) 3_1/2, 9.2~ N-SO TBo, TDS W/ SP CL CPLOS 4) 3--1/2 TDS BOX x 3-1/2 EU 8RD PIN X-OVER e 7641' 5) KOBE 3" MODEL "El" BHA · 7643' SHORT STRING (PRODUCTION) A) CM/ HANGER (BUTr-DOWN, RUE 8RD-UP) e 30.25' B) 3-1/2 Burr PIN(UP) x mS PIN(DCN~N) X-OVER · 31.08' C) 3-1/2" 9.2# N-SO TBO, TDS W/ ~ CL. CPt. GS D) 3-1/2 ms BOX x 2-3/8 EU 8RD PiN X-OVER e 7631' E) 2-3/8" 4.6~ N-80 EU 8RD PUP 0 7632' TAIL ASSEMBLY 6) 3-1/2" EU 8RD BOX x 3-1/2" BUTT X-OVER ~ 7666' 7) 3-1/2" 9.2# N-SO BUTT PUP (10') 8) 3-1/2" BUTr W1RELINE RE-ENTRY GUIDE e 7677' "B" ZONE PERFORATIONS 7476'- 7578' SQZD 7668'- 7765' 7788'- 7875' "C" ZONE PERFORATIONS 7938'- 7993' 8072'- 8163' 8180'- 8262' 8274'- 8328' "D" ZONE PERFORATIONS 8476'- 8511' DRILl_ABLE BP @ 9950' "G" ZONE PERFORATIONS 9968' - 10052' 10932'- 10938' 10954'- 10960' 10974'- 10980' 7" 29 & 35# @ 11127' ADL 17595 WELL NO. 27 COMPLETION SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (db(:] UNOCAL) DRAWN' DAC SCALE: NONE DATE: 2-13-9 1 · ~i07 i.._ // E-Z DRLLA?ggSO ,__ PB~ 11070 7*' AT' 11127 1) ~ DUAL I)CO ~ el'nd TOP BuTr I~1 2) 3,.V~' BUTT * ~ V2" ~)S DeL PtN ,3) 2,10JM 3 1/2' 9.~f ~ TI~ TUB ,~) ~ 1/2- 9.2f Neo 'ms PUP 5) 3jnt ~ 1/2' 9.2~ NK) TDS TUB ~ 6) 3 V2" 9.2~ Id00 11)5 Pl,t) 7) 3 I/2" *IDS by 3 1/2" EUE: ~-nd Moo "B" c~vtr,r 9) · V2" £~ Or.d · ~ V2- BUTT x 10) ,T 1/2" 9.2t NSO BUTT PUP 11) BAKER WIRE LINE REENTRY OUIDE 3" ID TOPS 30.25 i ~ 1.08 31.58 7528.94 75,36.99 76,30.59 x 7640,6,;3 7643.05 766,5,68 7667.40 7676.8 W.L. REENTRY BTM 7677.56 (NOTE SS LANDED .61 LONGER THAN TOI~ El) ~ 1~'..2" BUTT * 3 1/2" ~ DlJl. Pig c) 24q,,,0 ,~ V2- 9.2f .so Tbs TUB , o) z V2" T~s PUP i E) ~ 3 1/2, g~f Nco ms TUB V~" ~,s · 23/~' L~ ~ cams ov~ .2. 3/r' 4.~ E'~ a.~ ~ ."TOP OF.KOBE CAVITY" 50.25 ;51.08 32.51 7,528,03 7538.07 7631.57 7632.51 7642.38 EVAN K. HARNESS 2." Baroid Drilling Fluids, Inc. March 5, 1991 Mr. Don Chudanov Unocal oil and Gas Division P.O. Box 190247 Anchorage, Alaska 99519-0247 Re: BA-27 Workover Fluids Cost Mr. Chudonav: Enclosed are the workover fluids cost associated with the above referenced well. Please refer to the recap for sprcific details in reference to the operations involving the workover fluid. The costs are broken down as follows: Potassium Chloride - Technical service - Miscelleaneous - Total Well Cost $7,615.98 $6,669.22 $1,204.24 - $15,300.22 The KCL usage represents 2175 bbls of 3% KCL fluid. A total of 513 bbls of fluid were reported lost to the well. If you need any additional information or have any questions do not hesitate to contact me. Sincerely, BAROID DRILLING FLUIDS T.J. Olive Technical Sales Representative cc: Bush Neve' 2000 West Int'l. Airport Road, Suite A-10 · Anchorage, Alaska 99502 (907) 248-3511 ° Fax (907) 248-5390 MATERIAL Unocal Oil & Gas Division Material Usage and Cost BA-27 Workover UNIT USAGE COST/UNIT AMOUNT Potassium Chloride SAPP 100 LBS 261 $ 29.18 100 LBS 12 $ 87.00 7,615.98 1,053.24 TOTAL PRODUCT COST Technical Service Roundtrip Airfare Kenai Borough Tax TOTAL WELL COST Order Document Numbers: Char~es: Z34720 Z34721 Z34722 Z34723-02 Z34725 Z34728 Z34750 Credits: Z34744 Z344745 Z34746-02 16 $ 405.00 1 $ 111.00 4 $ 10.00 Amo~nt~ $10,785.07 17~545.11 12,754.64 10,944.00 1,760.80 5,262.40 6,601.00 $65,653.02 $20,540.07 11,640.81 i8~171.92 $50,352.80 $ 8,669.22 $ 6,480.00 $ 111.00 $ 40.00 ~15~ 30~. 22 Total Well Cost - $15,300.22 Unocal Oil & Gas Division OPERATIONS Baker BA-27 Workover 2-7-91 Move rig to Baker $~27, pump down tubing w/FIW, returns to production, pump water flood H20 down tubing. 2-8 Pump FIW down tubing, long string and short string, nipple down well head, nipple up BOP' s. 2-9 Nipple up bell, nipple and flow line, test BOP, short string, parted 10.5' below hanger, long string would not pull free, make up fishing tools, cleaned shaker and sand trap pits. 2-10 Pull and lay down 3 1/2" N80 dual string tubing. 2-11 Lay down guns, change top BOP rams, make up test plug and test, pickup BHA, RIH with 3 1/2" DP, tag up ~ 7747', PU kelly, circulate, TOH, lay down scraper, RIH. 2-12 RIH with bit and scraper, tight spot, POH, lay down scraper - RIH with bit, circulate bottoms up. 2-13 Logged - Rill with plug, set plug, POH, PU RTTS tool - test plug and casing. 2-14 RTTS would not go through tight spot. POH, run cement retainers, rig up BJ and squeeze. POH, rig down B J, nipple up, change out spool. 2-15 Drilled top retainer and cement down to bottom retainer - tested, POH. 2-16 Pressure test on squeeze - no good - recemented, waiting for cement to set up to drill out. 2-17 Drilled down to liner lap with 8 3/8" bit. POH, picked up 6" drill bit, drilling and pushing junk to bottom of 7", some additional 3% KCL FIW. 2-18 POH with 6" bit, RIH with casing scraper - displace hole with 3% KCL FIW, rigged up Baker 2-19 2-20 2-21 2-22 contaminated PH brine into pits. Diluted approximatel.y 10 to 1 with FIW. Lowered PH to 8.5 before discharging. POH, lay down casing scraper - pick up guns, RIH, rig up HALCO wireline, rig down wireline, shot guns, POH with guns. RIH, circulate, POH, lay down drill pipe - rig up, hydrotest and rig up to run drill string completion. Ran and landed 3 1/2" 9.1# lb. dual string production tubing. Built 110 bbls 3% FIW for additional volume. Moving rig from Well 37 and Well 6. Drilling Mud Record Petroleum Services COMPANY Unocal STATE Alaska CASING PROGRAM inch at ft. WELL Baker #27 COUNTY inch at ft. CONTRACTOR Pool Arctic Alaska LOCATION MGS SEC TWP RNG inch at ft. STOCKPOINT Kenai DATE 2/91 BAROID ENGINEER Thomas/Wol fe TOTAL DEPTH ft. DATE DEPTH A/EIGHTI VISCOSITY Yp GELS FILTRATION RETORT SAND CEC pH FILTRATION ANALYSIS feet lb/gal Sec APl PV 10 sec/ mi HTHP Cake SolidsOil Water % Mud Stripx] Pm Pr/ P,/P2Ci CA REMARKS AND TREATMENT __°F _°F 10 min APl __°F 32nds% % % me/mt Meter Lq Mf ppm ppm (See Operations Sheet) 2/7 7388 63 7.5 19,00( 2/8 7388 63 7.5 19,00( '" 9 7388 63 7.5 19,00() ./10 10,980 63 7.5 19,00() 2/11 10,980 63 7.5 21,00() 2/12 9950 63.4 7.5 17,00 2/13 9950 64.§ 7.5 28,00( 2/14 9950 64.c. 7.5 28,00( 2/15 9950 64.§ 13 28,00( 2/16 9950 74.2 13 28.00( 2/17 9800 65.5 13 30,00( 2/18 8590 64.E9 9 27,50( 2/19 8590 64.69 9 27,50( 2/20 8590 64.89 9 27,50(. 2/21 7677 65 8.5 27,50[ 2/22 7677 FIW moving rig . · RECEIVED NOV 2 2 1991 .Oil .& Gas Cons. tjull~misslo': ~chorage RECEIVED NOV 2 2 1991 Oil.& Gas Cons. Commission Anchorage ,IA 4 C 41 3 51 [9KOBEBHA J 8, F ,, 13-3/8' 68# /I ~ 3237' BAKER SC-1 PKR @ 5891' BAKER WELD SCREI GRAVEL PACK 2O-40 MESH OTTAWA SAND BAKER SUMP PKR ~ 6620' CDT RET @ 6645' CAST IRON BP @ 6650' 9-5/8' 47 & 53.5# @ 7232' TUBING DETAIL LONG STRING (POWER FLUID) CIW TUBING HANGER (BLITr) ~ 31.00' 3-1/2 BUTT PIN x 3-1/2' TDS PIN ~ 31.80' 3-1/2' 9.2# N-80 'IDS W/SP CL CPLGS 3-1/2' 9.2# N-80 'iDS PUP @ 5706.37' 3-1/2 TDS BOXx 3-1/2 EU 8RD PIN c~ 5813.66' 3-1/2 EU 8RD BOXx 3-1/2 TDS PIN ~ 5836.60' 3-1/2' 9.2# N-80 'rDS PUP ~:~ 5837.83' 3-1/2' TD$ BOX RE-ENTRY GUIDE ~ 5847.63' KOBE 3' MODEL 'B' BRA @ 581 3.95' SHORT STRING (PRODUCTION) CIW TUBING HANGER (BUTT) ~ 31.00' 3-1/2 BLFI-r PIN x 3-1/2' TD$ PIN @ 31.80' 3-1/2' 9.2# N-80 1'DS W/SP CL CPLGS 3-1/2- 9.2# N-80 TDS PUP ~ 5707.03' 3-1/2 TD$ BOX x 2-3/8 EU 8RD PIN @ 5803.95' 2-3/8 EU 8RD PUP @ 5805.26' SQZ'D 'A-6' SAND PERFORATIONS 6022'- 6052' 'BCD' ZONE INTERVALS 6092'- 6143' RECEIVED 6385'- 6438' 6454'- 6502' 6518'- 6568' /V0 V g 2 ~99j~ 6581 '- 6607' Alaska Oil & Gas Cons. ~ j !,,-mm-ssen ilnChorago SQZ PERFS F/6645.5'- 6647.5' SQZD WITH 200 SXS CMT 'D'ZONEINTERVALS 6663'-6683' 6700'-6727' 6788'-6800' ADL 17595 WELL NO. 17 COMPLETION SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 4-01-91 TEXAS @~ TOOLS UNIT 1058 Ilell)lee®8 1014 TUBING STRIPPER/PAC~[R $,000 psi Working Pressure H~S Service 1.00'Series DS322 1.25:~Serles DS323 phone: (713) $206 STATE OF ALASKA """ ALA,.,.,A oIL AND GAS CONSERVATION COMMIS,.,.ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Pull tubing ~ Alter casing __ Repair well __ Pull tubing __ 2. Name of Opera~3NOCAT, ) / 5. Type of Well: 3nion Oil Company of California I Development x Exploratory __ 3. Address Stratigraphic ~ P.O. Box 190247, Anch., AK, 99519 Service__ 4. Location of well at surface Leg ~ 2, conducl~or D Stimulate __ Plugging __ Perforate -x- Other __ 6. 'Datum elevation (DF or KB) 101' RKB ABOVE MLWeet 7. Unit or Property name MGS STATE 17595 8. Well number_ We_i. 1 No. 27 1985' FNL & 584' FWL, Sec 31, T9N, R12W, SM . _m~. n~ ."B" Zone at 7678' MD At top ct proo~ ~n'ten, a~ 2238' FSL & 1790' FWL, Sec 30, T9N, R12W, SM At effective de9pt~ 5 0' MD ( 7 6 91' TVD) 3640' FSL & 1921· FWL, Sec 30, T9N, R12W, SM 11,600' TMD (9258' TVD) 9. Per~ ,_ui'r~'~o_vsI ¢~.mber 10. APl numble.~ 3 - 20 36 8 50-- 11. Field/PR~ddle Ground Sh~ 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 3 4 0 7 ' Conductor 8844' Surface Intermediate Production Liner 3 0 02 ' Perforation depth: measured 11,600' feet Plugs(measured) · feet 9,258 9,950 7,691 Size 13-3/8" 9-5/8" 7 I! feet ' feet Junk (measured) Cemented 3070 sxs 1400 sxs 9255 sxs true vertical See Tubing (size. grade, and measured depth) attached sheet LS: 3-1/2", 9.2#, SS: 3-1/2", 9.2#, Measureddepth 3407' ~ueverticaldepth 2954' 8844' 6763' 8590'-11592' L-80, TDS L-80. TDS Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) See attached hi story Treatment description including volumes used and final pressure 14. Prior to well operation 0 Subsequent to operation 18 ri 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 0 0 - 274 0 16. Status of well classification as: Oil ~ Gas__ Suspended __ Service 17. I hereby cert!.f:~ that the foregoing is true and correct t° the best of my knoWledge. Gar~ ~!¢ Bush Regional Signed "~ /~~ %. ~,.~o~,, Title Form 10-404 Rev,(~15/8~ Drilling Manager SUBMIT IN DUPLICATE al UNOCAL SHEET A WELL RECORD PAGE NO. LEASE MGS STATE 17595 WELL NO. 27 SPUD DATE 2/7/91 COMP DATE 2/22/91 FIELD MIDDLE GROUND SHOAL CONTRACTOR PAA RIG NO. 61 LOCATION: LEG #2, CONDUCTOR #5 TYPE UNIT OIME 2000 1985' FNL & 584' FWL, SEC. 31, DRILL PIPE DESCRIPTION 3-1/2" 15.5# E&S T9N, R12W ELEVATIONS WATER DEPTH 102' PERMIT NO. 83-116 SERIAL NO.50-133-20368 RKB TO OCEAN FLOOR 203' TD 11600' TVD 9258' RKB TO MLW 101' DEVIATION (BHL) 4112' FSL & 1982' FWL RKB TO DRILL DECK 23.16' SEC. 30, T9N, Ri2W, SM RKB TO PRODUCT~ION D~CK)~9.16 COMPANY ENGINEER CHUDANOV, GRAHAM APPROVED~~3-- ~ ,~ ' HARNESS '~ ' CASING & TUBING RECORD SIZE 13-3/8" 9-5/8" 7" WEIGHT THREAD 54.5, 61 & 68# BUTT 40, 43.5, 47 & 53.5# " 29 & 35# " GRADE DEPTH REMARKS K-55 & N-80 3407' CMT'D W/3070 SXS S-95 8844' CMT'D W/1400 SXS HC-95 & S-95 8590'-11592' CMT'D W/925 SXS DATE PERFORATING RECORD INTERVAL E.T.D. 7476'-7578' 9950' 7668'-7765' 9950' 7788'-7875' 9950' 7938'-7993' 9950' 8072'-8163' 9950' 8180'-8262' 9950' 8274'-8328' 9950' 8476'-8511' 9950' REASON A~ ,_-~,~ENT CONDITION 'SQ~'~/450 SXS CMT PRODUCTION PRODUCTION OPEN PRODUCTION OPEN PRODUCTION OPEN PRODUCTION OPEN PRODUCTION OPEN LOWER PERFS ISOLATED BY CMT RETAINER AT 9550' (SEE ATTACHED PERF RECORD) DATE INTERVAL NET OIL INITIAL PRODUCTION CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS WE~J. HEAD ASSEMBLY TYPE: CAMERON IRON WORKS CASING HEAD: 13-3/8" SOW X 12" 3M HOUSING (9-5/8" CSG PREP) W/2 EA 2" 3M OUTLETS TUBING HEAD: 12" 3M X 10" 5M DCB SPOOL W/2 EA 2" 5M OUTLETS TUBING HANGER: 3-1/2" NOMINAL DUAL SPLIT HANGERS, BUTTRESS-DOWN, EUE 8RD-UP TUBING HEAD TOP: 10" 5M (RX-54) BLOCK TREE: 3 X 3 5M DUAL BLOCK W/3-1/8" BORE MASTER AND SWAB VALVES CHRISTMAS TREETOP CONN: 3-1/2" EUE 8RD ZONE B-1 B-2 B-3 C-1 C-2 C-3 C-4 D-1 G-2 G-3 MGS 17595 #27 PERFORATION RECORD MEASURED DEPTH CONDITION SQUEEZED OPEN OPEN OPEN OPEN OPEN OPEN OPEN ISOLATED BY CMT RET @ 9950' SQUEEZED ISOLATED BY CMT RET @ 9950' SQUEEZED ISOLATED BY C~T RET @ 9950' SQUEEZED ISOLATED BY CMT RET @ 9950' SQUEEZED 7476'-7578' 7668'-7765' 7788'-7875' 7938'-7993' 8072'-8163' 8180'-8262' 8274'-8328' 8476'-8511' 9968'-10,052' 10,758'-10,931' 10,932'-10,938' 10,939'-10,953' 10,954'-10,960' 10,961'-10,973' 10,974'-10,980' 10,981'-11,114' TRUE VERTICAL DEPTH 5845'-5847' 5914'-5984' 6000'-6062' 6106'-6145' 6200'-6266' 6277'-6335' 6343'-6381' 6487'-6513' 7707'-7781' 8431'-8598' 8599'-8605' 8606'-8619' 8620'-8626' 8627'-8639' 8640'-8646' 8647'-8778' DATE 02/07/91 02/08/91 PLATFORM BAKER 17595 WELL #27 (DA-27) WELL HISTORY PAGE 1 MW ETD COMMENTS 63 PCF 11070' COMMENCE OPERATIONS ON ADL 17595 #27 (BA- 27) AT 0600 HOURS ON 2/7/91. SKID RIG OVER WELL DA-27 AND RIG UP SERVICE LINES. RIG UP SLICKLINE UNIT AND TEST LUBRICATOR TO 1000 PSI. PULLED KOBE PUMP. SHEARED EQUALIZING PINS IN STANDING VALVE. RECOVERED STANDING VALVE AND RIGGED DOWN WlRELINE. CIRCULATED FIW DOWN THE LONG STRING TAKING RETURNS FROM THE ANNULUS TO PRODUCTION. STARTED GEd-rING BACK CLEAN FLUID BEFORE FIRST HOLE VOLUME HAD BEEN PUMPED. CHECKED WELL AND FOUND GAS AND SOME OIL WOULD FLOW FROM THE ANNULUS. PUMPED AN ADDITIONAL TOTAL DISPLACEMENT. SHUT-IN WELL AND MOVED BACK TO DA-6 FOR WIRELINE WORK. SUSPEND OPERATIONS ON ADL 17595 #27 (DA-27) AT 2100 HOURS ON 2/7/91. 63 PCF 11O70' RESUME OPERATIONS AT 0130 HOURS ON ADL 17595 #27 (DA-27) ON 2/8/91. SKID RIG BACK OVER DA-27 AND RIG UP SERVICE LINES. CIRCULATED DOWN THE LONG STRING TAKING RETURNS FROM THE ANNULUS TO PRODUCTION. SHUT-IN WELL TO MONITOR PRESSURES: LS=0 PSI; SS=40 PSI; ANNULUS 40 PSI. BLED OFF ANNULUS TO 0 PSI AND IT WOULD BUILD TO 80 PSI (TRAP PRESSURE). ISOLATED THE WELL FROM PRODUCTION. BLED ALL STRINGS TO 0 PSI AND CHECKED FOR FLOW (NO FLOW). DISPLACED VOLUME REQUIRED TO FILL THE CASING FROM BELOW THE TAIL PIPE TO THE BOTTOM PERFORATION. ISOLATED WELL FROM PRODUCTION AND BLED ALL STRINGS TO 0 PSI (WELL DEAD). REMOVED FLOW LINES. INSTALLED BACK PRESSURE VALVES AND REMOVED PRODUCTION TREE. INSTALLED BOP EQUIPMENT. REPLACED PISTON AND SEALS IN ANNULAR PREVENTER. 02/09/91 63 PCF 11O7O' FINISHED NIPPLING UP BOPE. RIGGED DOWN SCAFFOLDING. INSTALLED DUAL 3-1/2" RAMS IN TOP OF DOUBLE GATE CAVITY AND SINGLE 3-1/2" RAMS IN THE SINGLE GATE CAVITY. PULLED BACK PRESSURE VALVES AND INSTALLED TWO WAY CHECKS. PRESSURE TEST ALL RAM PREVENTERS AND CHOKE MANIFOLD VALVES TO 500 PSI (LOW) AND 3000 PSi (HIGH). TEST ANNULAR PREVENTER TO 500 PSI (LOW) AND 2500 PSI (HIGH). RIG TO PULL PRODUCTION EQUIPMENT. A~-FEMPT TO PULL COMPLETION AND FOUND SHORT STRING PARTED 10.55' BELOW THE HANGER. A~-FEMPTED TO PULL COMPLETION WITH 160K OVERPULL ON PLATFORM BAKER 17595 WELL #27 (BA-27) WELL HISTORY PAGE 2 DATE MW 02/09/91 (CONT) ETD R ECEIVE[) 2 6 1991 ~.~.Oil & ~as Cons. Cor~mission AnChorage COMMENTS THE LONG STRING-NO GOOD. DECIDED TO LATCH SHORT STRING WITH A SPEAR TO BALANCE STRING WEIGHT. WAIT ON FISHING TOOLS. MADE UP A BOWEN FULL CIRCLE SPEAR WITH 23' OF EXTENSION. RAN IN AND ATTEMPTED TO ENGAGE FISH TO 51' DPM (CAL TOF @ 42'). TRIPPED OUT WITH FISHING TOOLS AND RAN IN WITH 3-1/2" TUBING AND TAGGED THE TOP OF FISH AT 58.5'. RAN IN WITH SPEAR AND ENGAGED FISH. PULLED 55K ON THE SHORT STRING. LATCHED THE LONG STRING AND PULLED 145K TO PULL THE PRODUCTION STRINGS TO THE FLOOR. LAID DOWN LONG STRING HANGER AND FISHING TOOLS. PREPARE TO LAY DOWN DUAL 3-1/2" TUBING STRINGS. 02/10/91 63 PCF 11070' PULLED OUT OF HOLE LAYING DOWN DUAL 3-1/2" TUBING STRINGS. FOUND PUP IN SHORT STRING ABOVE KOBE CAVITY BADLY BENT. LAID DOWN KOBE CAVITY AND VANN SYSTEMS TUBING CONVEYED PERFORATING GUNS. 02/11/91 63 PCF 11070' CONTINUED LAYING DOWN TUBING CONVEYED GUNS (ALL SHOTS HAD FIRED). FINISHED BREAKING DOWN FISHING TOOLS AND TUBING HANGERS. CHANGED UPPER PIPE RAMS TO SINGLE 3-1/2" RAM BLOCKS. ATTEMPTED TO BACK OUT ALIGNMENT PINS ON TUBING SPOOL AND FOUND BOTH WERE TWISTED OFF. CHECKED MEASUREMENTS AND FOUND THAT THE TEST PLUG SEATED ABOVE THE PINS. SET THE TEST PLUG AND PRESSURE TESTED THE UPPER PIPE RAMS TO 300 PSI (LOW) AND 3000 PSI (HIGH). MADE UP BIT AND 9-5/8" CASING SCRAPER ON 3- 1/2" 15.5# DRILL PIPE. RAN IN HOLE AND SET DOWN AT 7436' DPM. PICKED UP KELLY AND ATTEMPTED TO WORK BY TIGHT SPOT (NEGATIVE). CIRCULATED WELL CLEAN AND TRIPPED TO DROP CASING SCRAPER. MADE UP BIT AND RAN IN HOLE. DATE MW PLATFORM BAKER 17595 WELL #27 (BA-27) WELL HISTORY PAGE 3 ETD COMMENTS 02/12/91 63 PCF 11070' 02/13/91 02/04/91 63 PCF 9950' (CMT RET) 63 PCF 9950' (CMT RET) CONTINUED RUNNING IN WITH BIT TO THE 7" LINER TOP AT 8590' DPM (DID NOT SEE ANYTHING AT 7436' DPM). CIRCULATED WELL CLEAN AND PULLED TO 7377' DPM. REAMED FROM 7377' TO 7470' DPM. CIRCULATED WELL CLEAN AND TRIPPED FOR CASING SCRAPER. RAN IN WITH 9- 5/8" CASING SCRAPER AND HIT TIGHT CASING AT 7436' DPM. WORKED THROUGH THE TIGHT SPOT AND HIT ANOTHER TIGHT SECTION FROM 7441'TO 7446' DPM. WORKED THE SCRAPER THROUGH THE TIGHT CASING ROTATING THE DRILL STRING BEFORE EACH PASS TO CHANGE SCRAPER ORIENTATION. DID NOT GET CASING FREED UP (REQUIRED 20-30 K OVERPULL TO WORK THROUGH TIGHT CASING). CIRCULATED WELL CLEAN FROM 7446' DPM. CONTINUED IN WITH SCRAPER TO THE LINER TOP OF 8590' DPM. CIRCULATED WELL CLEAN AND TRIPPED FOR BIT AND 7" CASING SCRAPER TO CLEAN OUT THE 7" LINER. RAN IN TO 9950' DPM PICKING UP 3-1/2" 15.5# DRILL PIPE. CIRCULATED WELL CLEAN. CONTINUED TO CIRCULATE WELL AT 9950' DPM (SOME GAS ON BTMS UP). ADD 3% KCL TO THE CIRCULATING SYSTEM. TRIP FOR "TMD" CASED HOLE LOG. RIGGED UP WIRELINE AND TESTED LUBRICATOR. LOGGED TMD/CCL/GR FROM 9344' WLM TO SURFACE AT 30 FT/MIN DATA ACQUISITION RATE. RIGGED DOWN WIRELINE. MADE UP EZSV CEMENT RETAINER ON 3-1/2" DRILL PIPE AND RAN IN HOLE. SET THE EZSV AT 9950' DPM. PULLED OUT AND LAID DOWN RUNNING TOOLS. MADE UP AND RAN IN HOLE WITH A 9-5/8" RI-rS PACKER. CONTINUED IN HOLE WITH 9-5/8" RTTS PACKER. PACKER SET DOWN IN TIGHT CASING AT 7440' DPM (8.20" OD ON PKR). TRIPPED FOR EZSV CEMENT RETAINER. RAN IN AND SET EZSV AT 7630' DPM. TRIP FOR A SECOND CEMENT RETAINER. RAN IN AND SET EZSV AT 7420' DPM. SQUEEZED "A-6" SAND PERFORATIONS FROM 7476' TO 7578' DIL AS FOLLOWS: ESTABLISHED INJECTION RATE OF 4 BPM AT 1200 PSI; MIXED AND PUMPED 300 SACKS OF CLASS "G" CEMENT WITH 0.15% CD-31, 0.6% FL-19, 0.2% A-2, AND 1 GAL/100 SXS FP-GL (SLURRY WT= 15.8 PPG; 10 BBLS FIW; AND 39 BBLS COMPLETION FLUID. STARTED MIXING AT 1540 HOURS. CEMENT IN PLACE AT 1625 HOURS. FINAL PRESSURE AND RATE WAS 2000 PSI AT 3 BPM. PLACED 285 SXS BELOW THE RETAINER, REVERSED OUT 10 SXS, AND DUMPED 5 SXS ON TOP OF THE RETAINER. PLATFORM BAKER 17595 WELL #27 (BA-27) WELL HISTORY PAGE 4 DATE MW ETD 02/14/91 (CONT) COMMENTS REVERSED DRILLPIPE CLEAN AND PULLED OUT OF HOLE. LIFTED BOP STACK AND REMOVED DAMAGED OCT TUBING SPOOL. FOUND A GROOVE IN THE ID OF THE CASING APPROXIMATELY 5/8" WIDE BY 3/16" DEEP RUNNING VERTICALLY DOWN THE CASING (CORROSION FROM PRODUCTION SCALE INHIBITOR). PREPARE TO TRIM THE CASING STUB TO FIT THE NEW ClW TUBING SPOOL. 02/15/91 65 PCF 9950' RECEIVED APR 2 6 1991 Oil & Gas Cons. Commissior, "~chorage TRIMMED THE TOP OF THE 9-5/8" 53.5# S-95 CASING STUB TO FIT CIW TUBING SPOOL AND "NX" BUSHING. INSTALLED 13-5/8" 3M X 11" 5M "DCB" SPOOL. TESTED THE SPOOL CONNECTION TO 1500 PSI. LANDED BOPE AND TESTED SAME TO UNOCAL SPECIFICATIONS. PULLED TEST PLUG AND INSTALLED WEAR BUSHING. MADE UP CLEAN OUT ASSEMBLY AND RAN IN HOLE. TESTED 9-5/8" CASING TO 1500 PSi. TAGGED CEMENT AT 7417' DPM AND CLEANED OUT TO RETAINER AT 7420'. DRILLED RETAINER AND GOOD CEMENT TO THE RETAINER AT 7630' DPM. CIRCULATED WELL CLEAN. PRESSURE TESTED SQUEEZED "A-6" PERFORATIONS TO 1500 PSI. PRESSURE BLED TO 900 PSI IN 30 MINUTES. TRIP FOR OEDP FOR BAIDEN HEAD SQUEEZE OF "A-6" PERFORATIONS. 02/16/91 65 PCF 9950' FINISHED PULLING OUT OF HOLE AND STANDING BACK CLEAN OUT ASSEMBLY. TESTED UPPER PIPE RAMS TO 5000 PSi. RAN IN WITH OEDP TO 7639' DPM. RIGGED UP CEMENTING UNIT AND TESTED SURFACE LINES TO 5000 PSI. EQUALIZED IN 150 SXS "G" CEMENT WITH 0.6% FL-19; 0.15% CD-31; 0.2% A-2; AND I GAL/100 SXS DEFOAMER. STARTED MIX AT 0558 HOURS. CEMENT IN PLACE ACROSS "A-6" SAND PERFORATIONS AT 0642 HOURS. BAIDEN HEAD SQUEEZED 10.5 BBLS OF CEMENT SLURRY INTO THE "A-6" PERFORATIONS FROM 7476'-7578' DIL AT I BPM WiTH 3300 PSI. SQUEEZE IN PLACE AT 0740 HOURS. PRESSURE ON SQUEEZE STABILIZED AT 2050 PSI AT 0900 HOURS. BLED PRESSURE OFF THE SQUEEZE SLOWLY AT 1230 HOURS AND PULLED OUT OF HOLE. PICKED UP CLEAN OUT ASSEMBLY AND RAN IN HOLE. TAGGED CEMENT AT 7413' DPM. PICKED UP AND WAITED ON CEMENT TO 2330 HOURS. PRESSURE TESTED 9-5/8" CASING TO 3000 PSI. PLATFORM BAKER 17595 WELL #27 (BA-27) WELL HISTORY PAGE 5 DATE MW ETD COMMENTS 02/17/91 65 PCF 9950' DRILLED GOOD CEMENT FROM 7413' TO THE RETAINER AT 7630' DPM. PRESSURE TESTED SQUEEZED "A-6" PERFORATIONS TO 1500 PSI-OK. DRILLED RETAINER AT 7630' DPM AND PUSHED JUNK TO THE 7" LINER TOP AT 8590' DPM. TRIP FOR 5-7/8" BIT TO PUSH JUNK IN THE LINER TO 9950' ETD (CMT RET). RAN IN WITH 5-7/8" CLEAN OUT ASSEMBLY AND TAGGED RETAINER JUNK AT 8590' DPM. WORKED JUNK THROUGH THE LINER TOP AND BEGAN PUSHING TO BO-I-rOM. SET DOWN AT 8645' DPM. ATTEMPTED TO CIRCULATE- NO GOOD. REVERSED DRILL PIPE CLEAR AND ESTABLISHED CIRCULATION THE LONG WAY. ATTEMPTED TO PUSH JUNK AND DRILL PIPE PLUGGED. CLEARED DRILL PIPE BY REVERSING. LAID DOWN 36 SINGLES OF 3-1/2" DRILL PIPE. RAN IN AND TAGGED JUNK AT 8833' DPM. CIRCULATED AND REAMED WHILE CHASING RETAINER JUNK TO 9814' DPM. 02/18/91 65 PCF 99OO' (RET JUNK) CONTINUED TO CIRCULATED AND REAM WHILE CHASING RETAINER JUNK TO 9900' DPM (COULD NOT PusH DEEPER). CIRCULATED WELL CLEAN. TRIPPED FOR 9-5/8" CASING SCRAPER (LAID DOWN 54 JTS EXCESS 3-1/2" DP). RAN IN WITH CASING SCRAPER TO 8590' DPM (7" LINER TOP). PUMPED 100 BBLS OF FIW MIXED WITH 1 DRUM OF DIRT MAGNET. CHANGED WELL OVER TO CLEAN 3% KCL/FIW BRINE. CLEANED THE SHAKER TANK. RIGGED UP FILTERING EQUIPMENT. CLEANED THE ACTIVE SYSTEM. CIRCULATED AND FILTERED COMPLETION FLUID TO 74.6 NTU'S. TRIP FOR PERFORATING ASSEMBLY. 02/19/91 65 PCF 9900' (RET JUNK) FINISHED PULLING OUT OF HOLE WITH CASING SCRAPER. PICKED UP 6" VANN TCP GUNS AND RELATED TOOLS. RAN IN HOLE WITH GUNS ON 3- 1/2" DRILL PIPE. RIGGED UP WIRELINE AND TIED IN GUNS TO THE FORMATION WITH GAMMA RAY. SET 'THE PERFORATING PACKER AND RAN CONFIRMATION LOG. CYCLED THE OMNI VALVE OPEN AND FIRED THE GUNS AT 1847 HOURS. PERFORATED THE TYONEK B, C, AND D ZONES AS FOLLOWS: 7678'-7765'; 7806'-7875'; 7955'-7993'; 8088'-8163'; 8191-8262'; AND 8476'-8511' WITH 32 GRAM DEEP PENETRATING CHARGES AT 8 HPF. OPENED THE RTTS BYPASS AND REVERSED THE DRILL PIPE CLEAN. REVERSED TWO ADDITIONAL DRILL PIPE VOLUMES. PULLED OUT OF HOLE WITH PERFORATING ASSEMBLY. PLATFORM BAKER 17595 WELL #27 (BA-27) WELL HISTORY PAGE 6 DATE MW ETD COMMENTS 02/20/91 65 PCF 9900' (RET JUNK) CONTINUED PULLING OUT WITH THE PERFORATING ASSEMBLY (ALL SHOTS FIRED). MADE UP BIT AND 9-5/8" CASING SCRAPER. RAN IN HOLE AND TAGGED THE LINER TOP AT 8590' DPM. CIRCULATED THE WELL CLEAN. PULLED OUT OF HOLE LAYING DOWN 3-1/2" DRILL PIPE AND TOOLS. PULLED WEAR BUSHING AND CHANGED TOP PIPE RAMS TO DUAL 3-1/2" BLOCKS. RIGGED TO RUN DUAL 3-1/2" PRODUCTION COMPLETION. PICKED UP KOBE TYPE "B" BHA AND TAIL ASSEMBLY, BEGAN RUNNING 3-1/2" DUAL COMPLETION HYDROTESTING BOTH STRINGS TO 5000 PSI. 02/21/91 65 PCF 9900' CONTINUED RUNNING DUAL COMPLETION HYDROTESTING TO 5000 PSI. INSTALLED DUAL SPLIT TUBING HANGERS AND LANDED THE COMPLETION. WlRELINE REENTRY GUIDE IS AT 7677' TM (KOBE CAVITY AT 7630' TM). LOCKED DOWN THE HANGERS AND PACKED OFF SAME WITH PLASTIC. INSTALLED BACK PRESSURE VALVES. 02/22/91 65 PCF 9900' (RET JUNK) REMOVED BOPE. INSTALLED DUAL BLOCK PRODUCTION TREE AND TESTED SAME TO 5000 PSI. LOADED STANDING VALVE AND PRODUCTION PUMP IN THE LONG STRING. RELEASED RIG AT 0600 HOURS ON 2/22/91. . STATE OF ALASKA · ALASKA OIL AND GAS CONSERVATION COMMISSION "¥ ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing ~ Variance __ Perforate x__ Other __ Well: 6. 2~~O~[r~:t°rcompany of California (II¢oT~e~velopment__ Da~3rselek~i°~Fog~eKB~SLfeet Exploratory __ 3.1~.d~e. SsBox 190247, Anch , AK, 99519--0247 Stratigraphic__ 7'Unitl~%°P~r~'~L~e 17595 · Service __ 4. Location of well at surface Leg #2, Conductor #5, Baker Platforlqt 8. Wellnumber Well No. 27 1985' FNL & 584' FWL, Sec. 31, T9N, R12W, SM At top of productive interval Top of "B" zone at 7668' MD 9. Permit number 2238' FSL & 1790' FWL, Sec. 30, T9N, R12W, SM 83-116 At effective depth 11,070' MD (8734' TVD) 10. APl number 4028' FSL & 1980' FWL, Sec. 30, T9N, R12W, SM 50-- 733-20368 At total dep. th 11,600' TMD (9258' TVD) 11. Field/Pool 4112' FSL & 1982' FWL, Sec. 30, T9N, R12W, SM Middle Ground Shoal 12. Present well condition summary Total depth: rED measured 11,600' feet Plugs(measured) RECEI true vertical 9,258 ' feet Effective depth: measured 11,070' feet Junk(measured) ~rE~ - 1 1.99]. true vertical 8,734 ' feet Aias...k,.a .Oil .& Gas Cons. Casin0 Length Size Cemented Measured dep. th ~l~0~g~iTr u e vertical depth Structural Conductor 3407' 13-3/8" 3070 sxs 3407' 2954' Surface Intermediate 8844 ' 9-5/8" 1400 sxs 8844 ' 6763 ' Production 3002' 7" 925 SXS 8590'-11592' 6568'-9250' Liner Perforation depth: measured See attached perforation record true vertical LS: 3-1/2", 9.2#, N-80 Buttress at 7420' MD SS: 3-1/2", 9.2#, N-80 Buttress at 7370' MD Tubing (size. grade, and measured depth) NONE Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal __x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: February 5, 1991 16. If proposal was verbally approved Oil ~x Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify that t,~'oregoing is true and correct to the best of my knowledge. I US~% ~"-""~' Title Signed GARY S.-~ ' ' REGIONAL DRILLING MANAGERDate ( - FOR COMMISSION USE ONLY Conditions of approval: No-~ify Commission so representative may witness I Approval No.(:;, / Plug integrity __ BOP Test __ Location clearance I / Mechanical Integrity Test w Subsequent form required 1"67'¢¢;-° .xpnrOVeQ CoPY ORIBINAi- SIGNED BY ~ - '---~%--~--~-~-' Date ~-¢- ~/' uomm~ss~oner Approved by order of the Commission ~ nNNIE C. SMITH Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MGS 17595 #27 PERFORATION RECORD ZONE B-1 B-2 B-3 C-1 C-2 C-3 C-4 G-2 G-3 CONDITION OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN SQUEEZED OPEN SQUEEZED OPEN SQUEEZED OPEN SQUEEZED HEASURED DEPTH 7476'-7578' 7668'-7754' 7788'-7872' 7938'-7972' 8072'-8149' 8180'-8250' 8274'-8328' 9968'-10,052, 10,758'-10,931, 10,932'-10,938, 10,939'-10,953' 10,954'-10,960' 10,961'-10,973, 10,974'-10,980' 10,981'-11,114, TRUE VERTICAL. DEPTH 5845'-5847, 5914'-5976' 6000'-6059' 6106'-6140' 6200'-6256' 6277'-6326' 6343'-6381' 7707'-7781' 8431'-8598, 8599'-8605' 8606'-8619' 8620'-8626' 8627'-8639' 8640'-8646' 8647'-8778, RECEIVED FEB - t 1991 AJaska .Oil .& Gas Cons, ~lisslo~ ~chora~ ' MGS 17595 #27 WORKOVER (1-31-91) I o · MOVE RIG OVER MGS 17595 #27, LEG #2, SLOT #5. KILL WELL WITH COMPLETION FLUID. · · INSTALL BPV'S, NIPPLE DOWN TREE, NIPPLE UP 5M BOPE. TEST BOPE AND CHOKE MANIFOLD TO 3000 PSI. · · · · CUT, PULL AND LAY DOWN DUAL KOBE PROD STRING AND TUBING CONVEYED PERFORATING ASSEMBLY. CLEAN OUT FILL IN CASING AND LINER TO 9950'. RUN 9-5/8" SCRAPER TO LINER TOP AT 8590'. RUN CASED HOLE PRODUCTION LOGS. · 10. PRESSURE TEST 9-5/8" CASING WITH RTTS PACKER. RUN 7" CASING SCRAPER TO 9950'. 11. SET CEMENT RETAINER IN LINER AT 9950' TO ISOLATE HEMLOCK. 12. 13. 14. SET CMT RETAINER AT 7585' AS A BOTTOM FOR SQZ. SET RETAINER AT 7450' AND SQZ "A-6" SAND (102'). CLEAN OUT RETAINERS AND CEMENT. PUSH JUNK TO 9950'. 15. CHANGE OVER TO CLEAN COMPLETION FLUID. 16. PERFORATE "BCD" ZONE UNDERBALANCED WITH TUBING CONVEYED GUNS FROM 7668' TO 8328' AT INTERVALS. 17. 18. RUN BIT AND 9-5/8" SCRAPER TO LINER TOP AT 8590'. RUN DUAL KOBE PRODUCTION STRING WITH PUMP CAVITY AT 7450'. 19. REMOVE BOPE AND INSTALL TREE· 20° RETURN WELL TO PRODUCTION AND MOVE OFF. NOTE: SBHP ANTICIPATED TO BE 2500 PSI AT 5845' TVD. WORKOVER FLUID WILL BE 3% KCL/FIW WITH NACL AS REQUIRED FOR WELL CONTROL BELL NIPPLE I FLOWLINE 3" KILL LINE WITH TWO 3" 5M VALVES I ri; rj~ KILL LINE FROM MUD PMP & CEMENT UNIT 13-5/8" 3000 PS! ANNULAR ! I I PIPE RAMS BLIND RAMS I 13-5/8" 3M FLANGE ADAPTER 3M x 5M 1,3-5/8" 5M FLANGE DOUBLE GATE 5M 13-5/8" SM FLANGE 4" CHOKE LINE WITH ONE REMOTE & 1 MANUAL 4" 5M VALVE CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) I I PIPE RAMS I 13-5/8" 5M FLANGE SINGLE GATE 5M 1,3-5/8" 5M FLANGE RISER I I I I I 10" 5M x 13-5/8" 5M ADAPTER CAMERON 5M SPOOL I 13-5/8" DOPE SM STACK BAKER PLATFORM (TESTED @ 3000 PSI) UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) DRAWN' DAC APP'D' GSB SCALE: NONE DATE: 11/16/90 ] 61 ~ 68# @3407' TOP OF LINER @ 8590' g-s/re" 40, 4s.s, ,/ 47 &: 53.5t¢ @ 7565' PBTD @ 11070~/ 7" 29 &: 35# @ 11127' 1 2 A J5KOBE BHA J TUBING DETAIL LONG STRING (POWER FLUID) 1) c~v ~NGER 2) :]-'1/2 BUTT PIN x 3-1/2 BUTT PIN PUP 3) 3-1/2" 9.2# N-80 TBG, BUTT W/ SP CL. CPLGS 4) 3-1/2 BUTT BOX x 3-1/2 EU 8RD PIN X-OVER 5) KOBE 3" MODEL "D" BI-IA · 7450' SHORT STRING (PRODUCTION) A) ClW HANGER B) ;~-1/2 BUTT PIN x 3-1/2 BUTr PIN PUP C) ;~-1/2" 9.2# N-80 TBG, BUTF W/ SP Ct. CPLGS D) ;~-1/2 BUTT BOX x 2-;~/8 EU 8RD PIN X-OVER E) 2-3/8" 4.6# N-80 EU 8RD PUP TAIL ASSEMBLY 6) 3-1/2" EU 8RD BOX x 3-1/2" BUTT X-OVER 7) :]-1/2" 9.2# N-BO BUTT PUP 8) 3-1/2" BUTT WlRELINE RE-ENTRY GUIDE · 7475' "B" ZONE PERFORATIONS 7476'- 7578' SQZD 7668'- 7754' 7788'- 7872' "C" ZONE PERFORATIONS 7938'- 7972' 8072'- 8149' 8180'- 8250' 8274'- 8328' "D" ZONE PERFORATIONS TO BE DETERMINED FROM CASED HOLE LOGS DRILLABLE BP @ 9950' "G" ZONE PERFORATIONS 9968'- 10052' 10932'- 10938' 10954'- 10960' 10974'- 10980' ADL 17595 WELL NO. 27 COMPLETION SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 1- 15-91 Perforotlone: Inl~ol PotenUol: Initial StlmulaUon: Re.ervolr Data= Cored Intervalo: DST Intervalo and Reoulto: Log Inventory: MIDDLE GROUND SHOAL ADL 17595 WEM. NO. 27 KENN & LOWER KENN CONOLOMERATE PLATFORM BAKER ;/10/03 bg 2. Slot S 1085' FNI., S84' PM, be. 31, TUN, RI2W, S.M. 11) - 4112' I~ 1082' FWL, Sea. 30, TUN, R12W, S.M. 70.4' KB 11800' MD 0258' TVO 11070' MD 8735' 13 3/8'*, 54.5, 61 and 68t K-SS end N-riO Cooing at 3407' Mth 3070 ox. eement O ~/B'*, 40, 43.5, 47 and 53.5t S-95 Cooing Get at 8ri44' with 1400 ox. cement 7" 29 and 35t S-g$ Unor Get at 8590-11592' Mth 925 ox. aomont _~ CompleUon Re~_ ord: Long Stdng: I. OCT 10" Dual tubing hanger 2. 3 1/2" N-B0 Buttnmo pupa 3, 3 1~" N-80 Bu~. ~blng 4. 3 1~" N-a0 Bu~o pup ~. 3 I~" Bu~s and 3 1~" 8RD XO 8. K~e 3" ~ *A* C~ ~-~50 7. 3 1~** Bu~u ~blng Short String: · ~ 1/2" Buttreoo pup B. 3 1/2" Buttru# tubing 3 1/2" Buttreoe ond 2 3/B" 8RD XO D. 2 3/8" riRD pup CAI run 11/25/87) B-I: 7476-7578' C-4: 8274-8328' B-2: 7668-7754* 0-2: 9968-10052' B-3: 7788-7872' 0-3: 109032-10938' C-1: 7938-7972' 10954-10980* C-2:8072-8149' 10974-I0080* C-3: 8180-8250' 92 BOPD. 0 BWPD, 16.4 UI~rD. 178 GOR 1. Add Job 3/29/04 10760-10874', 10992-11114' Performed mud raid oUmulatlon treatment uolng 1000 gal 10:~ HCL pm-fluoh, 2000 gal 6~ HCL - 1.5~[ HF and 1000 gal 109 NCL after flueh. 2. 11/28/84 fracture .Umulated well ~lth 13.$00 gal YF4 "PSD' treating fluid, 14000 poundo 20-40 Interpmp. Core dj1 0130-0148% Core t2 0148-0176' None DII./CNLA.DT. NOT,/~ SHDT Depth 32* d 57' 7363' 7370' 7371' 7388' 7420' 50' 736~ 7366' 7370' Vann guni PBD 11070' TDl1600' · I P · 13 3~B" 54.: ~ & eot csA ~, ., 7476' 7872' 8328' La 7~Uner Top 8590' 05/B"40.43.5 47 & 53.$f CSA gg88-10052' 10932' I0980* Amoco Production Company Northern Division 1670 Broadway P.O. Box 800 Denver, Colorado 80201 303-830-4040 Steve W. Souders Division Production Manager January 8, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 File: MAG-102-WF Subsequent Notice MGS 17595 Well No. 27 Platform Baker, Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-404, Report of Sundry Well Operations to notify you of work recently completed on MGS 17595 Well No. 27. MDG/mar Attachment a:mdgl01.d STATE OF ALASKA ALASK, ,~IL AND GAS CONSERVATION COMM, iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. NameofOperator Amoco Production Company 3. Address P. O. Box 800, Denver, Colorado 80201 4. Location of well at surface Leg 2, Slot 5. Platform Baker Ip~05'ofFNL. 58f+' FWL, Sec. 31-T9N-R12W S M prodLr'ctive interval ' ' At effective depth Attota~depth 11,600' MD, 9258' TVD 4112' FSL, 1982' FWL, Sec. 30-T9N-R12W S.M. 11. Present well condition summary Total depth: measured 11,600 feet true vertical 9,2 58 feet 5. Datum elevation (DF or KB) 79.4' KB 6. Unit or Property name MOS 17595 7. Well number 27 8. Approval number 7-892 9. APl number 50-- 733-20368 10. Pool MGS "BCD" and "EFG" Plugs(measured) 11,003'' 11 137' Feet Effective depth: measured 11,003 feet true vertical 8,669 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 3407' 8844' 3002' measured 7476' truevertica~772, 13-3/8" 9-5/8" 7~, to 10,980 ' to 8647' Junk (measured) Cemented Measured depth True Vertical depth 3070 sx 3407' 2954' 1400 sx 8844' 6763' 925 sx 8590'-11,592' 6568'-9250' Tubing (size, grade and measured depth) 3-1/2" N-80 BUTT TBG at 7340' Packers and SSSV (type and measured depth) None 12. Stimulation or cement squeeze summary None Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 38 15 0 70 75 Subsequent to operation 605 298 731 30 70 14. Attachments Daily Report of Well Operations l~ Copies of Logs and Surveys Run [] 15.' hereby certify that the foregoing is true and correct to the best of my knowledge -(~.~'~ /I-/~--~7 Form 10-404 Rev. 12-1-85 Title Date Submit in Duplicate ~MOCG =RSDUCT'IDN CCMP.~IY CHRONOLOGIC,~L RFPORT DENVER REGION .~ ~NCHOR.~GE DISTRICT ~¢'-~'- 0I/0~I88 ~c~: P.~GE 1 ~:¢~ JO]~ [NITZAT[ON REPORT: COMP/~N¥ OPERATED - RECOMPLETION - DEVELOPMENT ~PI ~0~332036~00 ...... ~L~'C ~6156 MIDDLE GRNDr'SHOALt"MGS 17595.*' 27~ :'KERAI O/S ST~TE~ ~L~SKA OPE~TO~: ~MOCD PRODUCTION , ........... , ....... , ............. , ....... , ........... ~ · .................. .,. ~NOCO W.[.: G2.EO00 "' ~ AUTH HORIZON 'ZONE: O1 - MGS ,17595~ 27 AUTH DATE 10/16/87, AU~'H COST $238000 CONTRACTOR(S) INFORM.~TION: P~R~ER, 0152~ RIG MOV~.. ON 1'1/21'/87 ' OENVER REGT~N $'~::: nNCHOR4GE ~ DISTRICT ...... .,..,..,. O1/ON/8~,.., ~¢¢ PAGE "M G S'" 17'5'g5'""'"27 ¥ .... MIUD L'E""'GRN'D'"'"'$ H'O',~' ~ ..... P ~ R K E FLAC 8~GISG-OI-Gt ~:PI 50'73120&GSOOt AUTH TD ~MgCO N.Y. G2.5OOOt gAYS F&OM SPUD OPE'R~TIgNS:' TD ..... I1G'Og ......rT't P'BTD' 1'1'~70~' NIPmLE UP PERT[NENT D~T~: PIG ~.J~VE 0N 11/2~/87 COSTS: DAILY WELL ~82Gg, CU~ WELL REMARKS: COMMENCED OPERATIONS 12:00 C N R 0 N T: M E"'"'D I S'T ~: BUT: ON .... ( H'R'S).~ .......... Q.:O .- Mit SKID RIG X RIGGING UP ].00- CIRC~ DISPLACE W/DIESEL ~.00 .- Ngt NIP'~LE DN TREE O.:g ....... O'THER'~ .........S ~.~ E'TY ' 'M EET'ING 6.0~- NU~gPt NIPPLE UP BOPS JO2 IN:TT~TION REPORT: DIRECTIONAL HOLE PIG CgN'T~CT D~'TA: CONTRICTGR B.~ CODE 8113I~t P.~RKERt RIG ~0:52, MGS 17595 27, NIEDLE GRND SHOAL, P~RKER 152, AMOCO PRODUCTION, FLAC ~NG15&-CI-6, ~PI 507332036~00t AUTH TD 11600, ~UTH COST $238000~ ................ ~MOCg""W~I', 62...~0g0i g~YS"FROM SPUD OPERATIONS: TO 11600 FT. PBTD l1700j GM DSL ::': COSTS: OIILY ~ELL $3~~ CU~ ~ELL CHRON TIM~ DISff~[BOTION (HRS): ............................. ! · 5 0-"' :~ ..... N U B 0 P 1.50 - TEST, TEST 3ORS CHG 3.50 - OTHER, PIG UP WIRELINE; CLI'T SS- RIG ON 3.50 - CIRCt KILL WELL W/DSL ~ .50 ..... T~IP ~ ...... O'UT" W/SS:'-' STD' 'B~CK'"TT"~STD'S .... ON'~'"[S ..... A'NU'"77 .... 'S'TD"S""ON SS LAY DOWN REST OF TUBING LAY DN ALL 'TAIL .PIPE 1.OO- OTHERt PULL/HANGER-TO FLOOR 3.00 - CIRCt TURN HOLE OVER .................... ........ &'SO'''''= ..... TRIn'~ ...........TUN .... W/LONG STRING MGS 17595 27~ MIDDLE GRND SHO~L~ PARKER 152~ AMOCO PRODUCTIONt ~OCU"'W-"T'~"62'.50CO'~ .... ~,~Y5 ~O~" SPUD 15'2'G OPEraTIONS: TD 1~600 ITt PBTD llTOOt L~Y DOWN 3%~TUBINGt F~ DSL COSTS: 3~:LY WELL tl2g~at CUM NELL $g710~ RSP~RKS: ~VE~ CHARGE ~CR ChVTTY ON 215T DEDUCTED 6000.0 FRON CUMULATIVE CHRON T[~F DISTRIBUTION (HRS): .................................. l.'.):~.~ - TRIPe TOH L.~Y DOWN T~ILPIPf 6.~? - LOG, ~UN C3L-~JDL-GR LOG ,~.00 - ~OO, LOG tiEING [NT~PPET~TE0: ~NCH DID LOG...,,~..,,.~0T ......... ' ~BL~' TO DO TH~U D~NVER 6.00 - PU~ P/U TUBING CONV~YED GUNS~ FOUND PIT'TING TUBING THRU VAR'[OUS PLACES 9.00 - OTHER, PUN TUBING HOLE TO L~Y DOWN CHECKING FOR FROSION gP ..PITTING. THIS"[S NOT SNELL ~OUNT IN ONE JOINT IN ST~ND OR ~ LOT ~HERE PIPE 4PPE~.~ED L~YING ~G&INST HOLE - HARD TO SEE SHOWS WHEN PIPE DRY . , ' ,,, ~g$ l?Fg.~ 2'7, ~I~'DLF GRND SHOAL, '~ER 1.~2, A~OCO P~0DUCTION~ ~LAC 5NG!SG-Ol-Gt apl 507.332936.~00~ AUTH TD 11600~ ~UTH COST amOCO W.I. 62,q00~ DAY5 FROM SPUD 1527 OPERATION5" 'TS"l'16'CO'~Tl PBTD 11070~ P/U 'PERF' GUN:.5'~ F'W'"DS[ ............................ COSTS: gAILY WELL $3065~ CUM WELL $127758 CHRON ~I~E DISTRIBUTION (HRS): 2.00- CIRC~ TURN HOLE OVER. 16,~3 - L/D~ LaY DN 3-1/2 TUBING RUN TUgING IN MOL: PON [.,~Y DOWN TUBING DUE TO PITTING IN TUBING 0,59- OTHER~ CHANGE Ra~5 TO DU~L ~.90 - PERF~ PU ~" PERF GUNS TUBING CONVEYED ........ .~GS 1-~g5' 2'Ti MICDL: g'RNO SFiO~Lt P&RKCR 1=2' A~,OCO PROOLJCTIONt ~:~ ..... ~.~..:. ~::: ..... :~:~- .~ - ~::::.. .... FLAC 5~G156-Ol-6t APT 5073~2036fiOg~ ~UTH TD llGOOt AUTH COST $238000t 4,0C0 W.:~. 62:~00~., O~YS FRO, SPUD 1528 . N.O0 - RU, ~IG U'n STAB ~OARO R~G UP NEATHERFORD DUAL .. ..................... SLIPS '+ EEV ..... RIG HYOROTEST/PU C~VITY ..... ~O.O,3 - RIG, ~/U - RIH WITH DUAL ~-1/2 TBG HYDRO TEST ~OOO PSI STRINGS ~ND ~O~CH LONG STRING ~ERFOR~TIgNS: ll/2~/~t TOP ~NT~ ~Tt 80TTO~ ~T~ PT, TYPE-OPEN.t.N0 'SHOT'/PT.' G, RE~F DI~. '0.5~0 IN, 'TOTAL 'N'O'~ "SHOT GUN-OTHER, SIZ6 N.O00 ~N~ PHASING 90 OEGt FLUID OIL, OENSITY ~.0 PPG, LEVEL ~00 FT ~/2~/B~t TOP ~ rTt 30TTO~ ~SN PIt SNOTSJ~T. N, P~F gI~'~. 0.5~0 INt TOT~E NO. SNOT '3~, G~N-nTN~, SIZ~ N.~OO~, TN, ~H~SING ~O. DEG, FLLJ~ OIL, DENSITY T.O PPG, LEVEL ~00 FT ll/25/~Tt T~P T~B~ FIt BOTTO~ ~2 FT, TYP6-OP~Nt SHOTS/FT. Nt P~ DI~. O.'~GO INt TOTAL 'NO. 'SHOT 33~t ' DENVER REG[O~,~ =.':,.-¢.::: 4NC!-IOR~G5 DIST,~[CT ~.;'=-::: ©1/0~/,5,~ -':.=::=:;: PAGE GUN-OTHFR, SI2~ q.O00 IN, PHASING FLUID OIL, DENSITY 7.0 PPG~ LEVEL 500 FT 11/25/~7, TOP 7935 FT~ 3OTTOM 7972 FT~ TYPE-OPEN~ ..... SHOTS'/'FT'; N~ PERF"'OI~M' "0'.'560 I'N~ .... TOTAL'" NO,' 'SHOT'"'I36' GUN-OTHER~ SI~E ~.000 IN~ PHASING gO DEG~ FLUID O~L~ DENSITY T.O PPG~ LEVEL 5DO FT 11/25/87~ TOP ..507~ FT~ ~O'T'TOM 8I~8 FT~ TYPE-OPEN~ ..... 5HOT~/~T. ~ P~RF D'I~. 0,~60' IN~ TOT~L' NO~ .... SHOT'3O~ ' GlJN-~THER~ SI7'~ ~.000 !N~ PHaSiNG FLUI~ 01L~ ~6NSITY ~.0 PPG, L~V~L 500 FT ~1/2~/~T~ TOP 6~80 FT~ 8~'tTOM 6250 FT~ TYPE-OPEN~ GUN-OTHER, SIZE ~.000 IN, PHASING FLUID OIL, DENSITY 7.0 PPG, LEVEL 500 'FT ' 11/25/$79 TOP 8'2'7~ FT9 BOTTOM 8326 FT~:TYPE-oPEN"~ SNOTS/FT',' ~', PERF 'DI~."'C';5'80 IN'~ TOTA~"N'O'; ..... GUN-OTHER~ SI$E ~o000 IN~ PHASING FLUZD OILy DENSITY 7.0 PPG, LEVEL 500 FT MGS 17595 2'7~ MIDDLE GRND SHOAL, P.~RKER 152, AMOCO PRODUCTION? ~ ~ -¢. ~- ~- -.- ' ;L~C ~q6ISG-Ol-6~ ~PI 5073.3203G800~ AUTH T~ llGO0~ ~UTH COST ~MOCO ~.I. 62.~000~ D~Y5 FROM SPUD 1529 OPERATIONS: TO !160.'~ ~T, PBTD 11070, ORE PA'3E TO SKID RIG~ EM...,.P. SL COSTS'" D~[LY WELL ~1~26~',' CUM'"WELL $281326 .......... CHRON TI~E DIS'T~IBUTION (HRS): 3,50- RTG~ ~IH W/3-!/2 DUAL TBING 1.00- RD, ~IG DONN HYDRO /EST TOOL 2.30-' LOG~ ' PIN W/WIRELINE CORRELATE GUNS WITH"'L'OGS '' ' ].50 - NDBOP, NIPPL~ DO~N BOPS ~.00- NU, NIPPLE OP TREES l*"O0""-' ~ERF', DROP"~A~ FIRE' GUNS "~IL[ .... STARTED '~LO~'ING IN 5 MIN. - M~DE 42 ~BLS" [ST HOUR SI IN ~ELL DUE TO PLATFORM 5I - SHUT IN ]0 MIN OPEN UP PSI WAS 700 PSI H~VE R~TURNED 390 BBL5- NO FLUID~ANNULU5 FULL THIS .................... FOR"7 H~S '" FL'ORING 'DPPROXIM~TEUY]55-"~'~L-S--H'OUR"H~D METE~ PRO~LE~5- 'DU~ ~T~R PU,P'ALL RETURNS ~RE DSL. 7.50 - OTHEr, CLE~N RIG ~ND PITS RE~DY DECK TO ~KID MGS ~759S 2~, MIDDLE GRND SHO~L~ P~'DKER [52~ AMOCO PRODUCTION~ FLOC 5~6~E6-0~-6, ~PI EC7~t20~6400~ ~UTH TD ~]600, ~UTH COST ~OCO W.T. ~2.EO0O, S.~YS ~OM SPUD OPCR~TTSNS: TD [[600 ~T, P~TO ~[070, RLS~ ~[G AT [2 NOON COSYS:"D,~ILY ~ELL"~iOO~QE, CUM' WELL t3~7[ P~GE CHPON TI~ D[$'TP[~,UTTON (HR$): '3,.,~© - OTHER, ,"',ONITOR NELL NELL rLONING .~PP ~5 BBLS PER HOLI~ ~LL DSL SO~ ~S UNHOOK S~V~C~ L[~S ~-00'- ~Ot SK~D 'TO CENTER' PLATFORM Z.SO- O'THERt ~OVE DECK 5QU]P~[NT ~.GS !75qS 27, ~IDDL~, GRND SHOAL, P.~RKER 1527 ~OCO PRODUCTION, ~L,~'C ....846156-01-Gt 'AP~"50T332016800~ .... :~U'T'H"TD"llGO0~ ...... ~'UTN'7'C'OST'$2]8000t ~MOCD W.~. G2.SO00t DAYS FROM SPUD 1531 OPERATIONS: TD llGO0 FT COSTS: CU~ WELL $3821T1 2~.00 - OTHER, PUMPING NO G~UGF MGS 17595 2'7, MIDDLE GRND .SHOAL~ P~RKER 1'521 AMOCO pRODuCTION~ ooo, ~MOCO o2.50Out D~YS rRO~ S~U' 1532 OPERATIONS: TD II600 ~T COSTS: CU~ WELL S3821~I CHPON'""TIME gISTR'!:~U'TION ..... {HRSI: :' 2~.00 - OTHER~ PUMPING NO GAUGE .... ! 1 I~o /- ........ MSS 17595 27, ~',I~DLE GRND SHOAL, P~,RKER 1521 AMOCO PRODUCT]ON, ...............· ... .. -, ~ ..... .... ..... ..... ~ ~ ~: ~ ~ ..~ .. ..... . ..: ~ ~k ~: .......... ~MOCO W.~. 62.50001 gAYS FROM SPUD OPERATIONS: TD Ii600 COSTS: CUM WELL 24.00 - OTHER, PUMPING NO GAUG~ MGS 17595 27, MIDDLE GRND SHOAL? P~RKER 1527 AMOCO PRODUCTION~ ~:L~C'"-8'~'GI56-C'l'-61 ~m"I 5073'320ZG800,~ '~U'"'rN~--TD llGOOt--AUTH"--C-O-ST'-$2]6OOOt ~OCO ~.I. 62,SOOOt DAYS FRO~ S~UD 1534 QP6R~TIgNS: T~ 11600 PT COSTS: CU. WSLL $,382171 CHRON TIW5 ~ISTRIRUTION ~.,.00 -..q. TN=Rt PUmPTNG NO GAUGF_ MGS 17595 27~ MIDDLE GRND 5HO~L?,~A~KER 1'52~ AMOCO PRODUCTION~ FLOC ..... :B4GI'SG-CI-6,' &PI 5073'32036500, ~UTN TO' 11600~ AUTN"COST $238000.~ ...... ~MOCO W.I. 62.50C0~ DAYS F~O~ SPU~ 1535 OPERATIONS: 'TO 11600 =T COSTS: CUM WELL $3~2171 CNRON'"-'T~E DI$TRIB'UTION'(HR5): 2N.O0 - OTHE~ PUMPING NO GAUGE ,~GS 175OS 27~ ~'~IDDLF GRND SHOILt P,aR~ER 152~ AMOCO PRODUCTION, FL~'C ~6IS6-OI-G~ 'AP~' 5073'32016800~ ~UTN"'TD ~MOCO W.;. GP.5OOOt gAYS FROM SPUD OPERATIONS: TD ItGO0 ;T COSTS: CUM WELL $382171 RE~RKS': 3 HR TEST: JET JUMP BBLS FLU%O' 159: GRAVITY 34.0; BPOPD '~3,~ ~T 30~70 PSI CHRON TIME DISTRIBUTION 24.00 - OTHER~ PUMPING NO ~ ................... ...... ........ ~.-~ ............................... . ~ 12/04/87 MGS !7%g5 27~ MIEDLF GRND S)~CSL~' P~RKER 1.52, 'AMOCO PR'~DUCTION~ ~L~C 5~61~G-01-6~ ~PI 5073'32036800~ ~UTH TD llGO0~ ,~UTH COST $23~000, ~MDCO W.I. GP.SDO0~ D~YS FROM SPUD 153'7 OPERATIONS: TD 11600 FT COSTS: CUM WELL REMARKS: 6 HR TEST: BBLS FLUID 30~ 2 65.2% WATER; MCF 2~HR:292 GDR=Ggl: NO FLUID L;VEL aNNULUS SURGING-FLOWING TNTE~MITTENLY. P0/O 9~3 '9 ]50",~ PSI'; 'GTY '3~',G ........... CHRON TT~5 OISTP[~UTION (HRS): 2~.Q~3 - 0THCR~ PUHP[NG N0 GAUG~ ..... /05/ MGS 17S95 27~ MIEDLfi GRND SHOqL~ PARKER 152w AMOCO PRODUCTION~ ' FLOC 5~Gl~G-OI-G~ ~P! 50~3320~G800~ ~UT~ T~ llGOOw AUTH COST $238000~ AMOCO W.I. 62.5000, PAYS FRON SPUD 1538 OPEP,~T~ONS: TO 11600 FT COSTS: CU~ WELL $3~2171 ".3=NVFi~ REGI.fl..,N ~::: ~,:"JCHO,q.aGE DISTRICT ,::-.'t--~.: 01/0q/88 *~:.:: PAGE 7 RE'~&RKS: ] HR 'TEST: 5BLS FLUID 151 @ 64.6% W~TE~; ~CF 24HR:2~2 GOR=659,~ GTY 3S,6 5POPDz979 ] 3500 PSI CHRON TI~ OISTRI~UT~ON (HRS): 2~o00 - g'TH~, "PUMPING Na'G~UG~ ~ 1,2/06/8'7 MGS 17.~95 .27~ MIDDLE GRN9 SHOAL, P~RKER 152~ AMOCO PRODUCTION, FLAC 546.156-01-6t ~PI E07'332036,~00~ AUTH TD !,.,~,~.OOt .... ~.gT.U,,.C, OS,~ ~2,3. a00,0, AMOCO""'W';Z',' 62',S0'00,' DAY.S FRO~ "SPUD' OPERATIONS: TD 11600 FT COSTS: CUM WELL PEMAR'KS: ] HR TEST: B~LS FLUID 165.9 2 ~9.'3% WATEr: MCF 2~H~:2'79 .............. GaRbS1'6' 6Tv ]~'0 '~PopD=lo~a· ~ '3~'oo Psi CH~ON TZ~E D~STRIBUTION 2G.O0 - OTHER, PUMPING NO G~UGE . MGS 17595 27.t MIgDLE GRND SHOAL, PARKER 152~ AMOCO PRODUCTION, ................. ~ .~ ~.,.....~ ~. ~. ...... ~ ... ~ .... ~ ~ ~ :~ ~ ~... ~ ,.~ ~: ~: ~ .~... ~ ,..~ ~..~ ....,. ::: ~: ~. ..... ....... ..... ... FL&C ~6I~6-OI-Gt ~PZ 50735203GSOgt ~aUTH TD IIGOOt ~UTN COST ~MOCg W,~, 6~,50~0~ ~YS F~CM SPUD 1540 ~PEPAT~ONS: TD 11600 FT COSTS':' 'CUM" WELL $3~2ITI ~E~AR~S: G HR TEST: BBLS FLUID 3I~ 2 GO.7~ WATER: MCF 2~HR=]16 GO~=6q~.T GTY ~POPg:g~ ~ ]500 PSI ANNULUS FLOWING CHRgN TIME D~S~RI~UT~ON (HR.S): 2~,'O0'"--'OTNEPt PU~P~NG NO G~UGE .... MGS 17595 2'7, MIDDLE GRND SHOAL, P~RKER 152t AMOCO pRODUCTION FLOC 8N6156-01-6~ AP1 507332036800, AUTH TD llGOOt ~UTH COST $238000, ~MOCI3'I~oI'.' 62.50C0~ ~aY5 FRO~ SPUD 15'41 OPERATIONS: TD 11600 FT COSTS: CUM WFLL RE~RMS: 5 HR TEST: B~LS FLUID '' GDP=6g5 GTY 3G.1 LIFTING 983'2-3500 PSI ~NNULUS'FLOWING CHRON TIME DISTRIBUTION (HRS): 2~.00 - OTHERt PUMPING NO G~UGE ........ 12/09/87 :.'- ~: :.': MGS 17595 27, NICUL.~ GRND SHO~Lt P.~RKFR 1527 AMOCO ORODUCTION, --~-. .... ..x-.~;... .".'~'~'~~:~~~~~0~:~~~:~:~:"-."~" -'.' - - -- ' - - ' D,_;: N V E P., DISTRICT ~** 01/0~*/88 **::: PaSE ,~ FLOC 8q6156-C1-6~ Ar~I $0v332036800~ AUTN 'TO 11600~ ~UTH COST $238,000~ ~MOCO W. ~. 62,5000~ D,~Y5' FROM SPUD 15G2 OP~TZ~NS: TD 11600 ~T COSTS: CUre"WELL" $382171 RE~ARKS: 3 H~ TEST: 3BLS FLUID I2g~ ~ 59.~ NTR GOR 565 ~PCPD =g~2 ~ 3500 PSI ~NNULUS FLOWING CHRON T~E DIStribUTION 2N.g~ - OTHEP~ FU~PING N~ GAUGE C: .... 12 / 10 / 8, T ~:: , MGS Z?_"~g:5 27,~ MIDDLE GRND SHO~L~ P~RKER 152~ AMOCO ~RODUCTION~ FLAC 8N6156-01-6~ API 507332036800, ~UTH 'TO 11600~ ~UTH COST $238000~ ~M'OCO"W"~'~' 'G2"'~O00'~ ~YS FROM"SPU'~ OPm A .,.R TIONS TD Ii600 COSTS: CU~ WELL $382iTI CHRON TINE gISTR[BUT~QN (HRS): ............... 2~.OO"'-',' 'OTHSR~ .... PUMP['NG NO 'G~UGE · MGS 17%q5 27~ MIUDLE (.';RN~ SHOAL, PAqKER 152, AMOCO PRODUCTION, FLOC 8q6156,-Ol-G~ &PI 50~332016500, ,aUTH TD 11600~ ~UTH COST $238000~ ..... ~MDCO W.'[, 62.5000~" D~YS FROM ·SPUD OPERATIONS: TD 11600 FT COSTS: CU~ WELL CHRON TI~E DISTribUTION 2q.O0 UTHE~ 'PUMPING NO G~.UGE ........ ...... 1121 ........ 1..~ 87 * -,- ...... .,- MGS 17595 2'?, '~IDDLE GRND SHOAL, PARKER 152~ AMOCO PRODUCTION, OPER&TIONS: TD ll600 FT COSTS: cu. W LL REMARKS: 2 HR TEST ~L ~LUI~ i3T: BS~ 57: MCF 3~G: LI~T IN I603 ' "~250 FL 2"1~81 CHRDN ~[ME DISTRIBUTION (HRS): 2~.00 - OTHE~ PUMPING NO G~UGE . MG5 ZT%q% 27~ ~:I~DLE GP, N~ SHO~L~ P~RKER ~52~ ~MOCO PRODUCT[ON~ ~L,4C ~66156-01-6t ~MOCO ~.I. 62.5000~ g~Y5 FPQM SPUD 1549 OPERATIONS: TD. 11600 FT COSTS: CU~ N~LL RE~ARK5: 2 HR TES'T ~BL FLUID 136~ BSN 62; NCF 37~; GOR GO2 'LIFT IN llq5 ~ 3250 PSI; FL 1580 CHRON 'TIM6 DISTR'IBUTION (HRS): 2~,09 - OTHS'P~ 'PUMPING NO G~UGE MGS 17595 2'7t MIDDLE GRN,O SHO,~Lt PARKER 152t A~OCO PRODUCTION.t :~¢~:~:~.~:~::::~:~ ~:~:~¢~;.':,'~:::~:.~ ~':.-'--'-,'-~,,'-,~,' ~.~...~ ~.:.,~.~.,..,.....,..,.., .,.,. ,' ,.. ., , ~,,. ~ :~ ~ :~:~¢. ~:~:~,~ :~,~;~:~:~'~'",.~:~,:~ FLOC 8~6156-01-6t ,~P! 50'7~,. ~3~016800~ '~ AUTH TD l1600t ~UTH CaST ~MOCO W.!· 62.5000, ~Y5 FRO~ SPU~, 15q7 ~E~RK$: 6 HR TECT~ ~: ~ GO'R 57~: LI'FT IN t61~ 9 3~50 PSI: ~t CHRON TINE DIST~!BUT!ON (HR5): 2q.O0 - OT~ER~ PUMPING NO GAUGE NG5 175~5 27, ~IEDL~. GRND 5HO~L~ PA~KSR 152, AMOCO P~ODUCT'ION~ FLOC 8q6156-O1-6t ,~PI 507]]2036800~ ~UTH TD 116~0, ~UrN CaST $238000t ~MOCO W.I, 62.~000t DAYS FROM SPUD 15~8 OPERATIONS: TD 11600 ~T ~O$'T$~ ~U~ ~ELL ~.2~ ' REN~K~: FLU~O LEVEL I6~ FT CNPQN T~E ~T~I~UTION .GS 17~5 27, ~I,DDLE GRND SHOAL, Pa~WER 1~2, A~OCO P~,CDUCTION, ~ ~ ~ .~ .~ ~: - :~ :~ ~ ~ :.. ::: ... ::: .; ::: :.. ... :..... :....: :.. :..... ,..~ :.. :'- :.. --.---.- -,: -.. ' -- ::: FLa[ .~q5156-01-6~ a°I n~OCC ~,!, 62,590.P, ~aYS ~RO~ SPUD 15~9 OPERATIONS: TD 11600 COSTS: CUM WELL ~]82171 REMARKS: TST 6 HR5: BBLS OF FLD ~10; GTY 3~,G; BSW 59,9; MCD 379/2qHR CHRON TIN5 DIST2IBUTION (HRS): 2~.OO - O'TH~P~ PUMPIN~ 12/17/8.7 DISTRIC? ::"-,',:.':- 01/0q/88 **:.': PAGE I0 MGS 17"99- 27~ ~'ItP.LEr~ . ,r.,RND, SHO~L~ PARKER 152, .AMOCO ~RODUCTION~ .,: ...... :,,:. :~ .~ -'- , , ...... ~. ~'., ... :1.. g :;: :;: ::: .... ..... ~ ..... ...,. '.,': ....... ~ .'1.: ~...":..':: ~ ~: :~: "'... ::: ~::.." .......... -,...- ...," .,."'.,.'" .,.'" ::~ ::: ::: ..-'" "".,. "'... -~'" "'.,- '".,- .,- ~ :::" -.-"' ..... -,~ .... :1: o '.. ~: ~ :;'- :;: ~ :1: ::: :,': '.~',-'" ::: ::: ~ ~' ~ ~ '" ..... "' ' ' .............. ~': "' '~ F:LAC ._B~6156-01-~ APl 5C73-~2036..a00, ~UTH TD 11600~, AUTH ClqST $238000~ ~MOC'['] W"I,' 6'2.5000~"'D~YS lmRO~,.'"'SPUD '1550 OPERATIONS: TD llGO0 F'T COSTS: CUM WELL $'3a21'71 CHRON TIME DIS!RIOUTION (HRS): 2N.230 '- OTHER~ PUMmING NO GAUGE~FLUIO LEVEL 1751' PT ~GS 175.95 27~ MIDDLE GqND SHLI,~L~ P~RKEe 152~ AMOCO PRODUCTION~ FLAC .,5q6156-01-6~ APl 59~332036~00~ AUT~ TD 11600~ AUTH COST OPERATIONS: TD 11600 ~T COSTS: CU~ WELL .~3a21~1 RE~AR~%: 2?;TEST 6 HRS 3~,3 BBLS;GTY 3~.?;~SN S6.?;~CF 90;2q HAS ............................ ....... .... MGS I~'.~95 27~ 'v'I~PLI: ~RND SHOaL~ '~ARKER 152~ AMOCO '~ROSUCTION'~ FLOC ,SqG15G-Cl-6~ a~I 5073320)6800~ ~UTH TD ll6OO~ ~UTH COST $238000~ .aMOCO ~.I. 62.5000~ DaYS FRD~ SPUD 1ES~ OPER~TION5: TD 11600 FT COSTS: CU~ WELL $38,2171 CHRON T~E DI5TRI2UTION (HRS): 2~.00 - OTHEr, PUMPING NO GUAGE: FLUID, LEVEL 1628 F.T ............. 12120/g7 FLOC 8q6156-C1-6, AP1 507332036S00, aUTH TD 11600, AUTH COST $238000~ ~MOCO W,I. 62.5000, D~YS FRO~ 5~UD 1553 OPEraTIONS: TD I16CO mt COSTS: CU~ WELL REPORTS: 6 HR TEST: !?l ~BL FLU!E; BSEW 56%; MCF9 80.5; GOR ~g5; GRAVITY 3q.7: BPOP~ 160! at 3qO0 PSI: FLUID LEVFL 1516 CHRDN TIME DISTRIBUTION {HRS): 2~.30- OTHER, PUMPING- TESTING --~... 12/21/87 ~GS 17595 27, ~I~3L6 ~RXD SHOAL, P~PKE~. t52, A~OCO PRODUCTION, . :.. :D :~: :.. :...~'~ ..... ~ :;: ~ :.. ~ .,. :.-... ...-.- .,- :1: '" ~ ~ ~ :.- :l: :l: ........ - :l: ~- -~ -,- .. :~ ~. ~ -,- '.- .... FLAC 8q6156-01-6, AP1 5C73t2036800~ BUTH TD 11600~ IUTH'COST $236000'; OPEP~TIONS: TD 11600 ~T COSTS: CI.J~ WELL $3~2171 CHRON 'TIME DISTRIBUTION (HP, 5}: 2~.00 - OTHER~ PUMPING NO GUAGE; FLUIO LEVEL ~GS 175q. 5 77~ NIC. DL,~: $RND 5HO.~L~ P~K=R 152, AMOCO PRODUCTION FLOC 8[~6156-01-G~ .~PI E073320~6800~ ~UTN TD IIGO0I AUTH CO'ST '$238000.~ ......... ~MOCO W.I. 62.5000~ O~VS FROM SPUD 1555 OPERATIONS: TD I16C0 ~'T COSTS: CU~ ~ELL $382171 REMARKS: G HR TEST: 36g BBL FLUID: ~5CW 58,[+~; MC;D"81"I': 'GDR' 531; G~VITY 36; BPOPD 1669 ,D '~00 PSI; FLUID LEVEL 1768 FT. CHRON TINE DIS'T~IPUTION 2Q.qO - OTHER~ PUMPING - TESTING ~SS l?Sq~. 2'7~ NI~DL? GRND SHOAL, P~R'KER 1'~2, 4MOCO PRODUCTION,' FLOC B46156-01-6~ oPI 5073329~6~0~ aUTH TD 11600, aUTH COST $23~000, aMOCO W.I. 62.EOCO, O~YS FROM SPU~ 1556 OPERAT'I~NS: TD 11600 'FT COSTS: CUM WELL CHRON TI~ DISIRIBUT!ON (HRS): 2~.00 - OTHER~ PUMPING - NO GU~G[. FLUID LEVEL ......... /2~/ ........ I .,: 87 ..... .... ~.G'S' 17595 27~ MIODLE GRND SHO~LI P~RKE,~ 152~ 'A..'40CO 'PRODUCTION'~ ..................................................... FLAC 8~6156-C1-6~ a~I 507332036]00~ ~UTH TD iI600~ AUTH COST $236000~ ~MOCO W.I. 62.5000~ D~Y5 FROM SPUD I55~ OPEP~TIONS: T~ llGeO COSTS: CU~ WELL S~2171 ~ENARK5: 6 HR TEST: 36~ ~B,L FLLJIS; BSEW 57.3%; MC~D 232: GOR 3691 GRAVITY 35.~; BPOPE 16.52 C~RON TIME UISTqIBUTION (HR5): 2~.90 - OTHER~ FU~PING - TESTING . aNOCO N.I. 62.50C©~ SSYS CROW SPUR.., 1558 OPEPATIONS: T5 COSTS: CU~ NELL $32.2~T1 CHRON' 2N.O0 - OTHFR~ PU~PING - NO GUAGE: FLUIO LEVEL l~N3 FT ~GS !759'5 27, MI~DLE C..RND SHO~L~ P:IRKER 1'52~ AMOCO PRC..DUCTION, FLAC 3~6I'56-0I-6~ ~1PI' 507332036800~ .... AUTH' TO" l'lGOO~ .AU"TN"COS'T $238000~ .AMOC[t W.I. 6,Z.,,50(]0~ ~AYS FROM SPUD 1559 OPERATIONS: T~ IiCO0 ~T COSTS: CU,,", WELL $38217I REMARKS: '6' HR T'~S'T; ........ 342 '33L 'FLUID: '~$EW .~.?.3%;' ~4C'~D 3~+I; GOR,""58~; G:~VITY 35.3: RPOPD i655 ~ 3~+00 PSI; FLUID LEV.FL I7~.~ CH;ION TI,ME D!S'TRI~,UTION (HRS): 2~+.QO - OTHER~ PUMPING- TESTING , .............. ~OS I?.~.g5 2'T~ ~LE'GRN~ SHO~L~ P~RK~R 152~ ~OCO PRODUC'TION'~ FLAC 8~61~6-01-6~ API 5~332036500~ ~UTN TD 11600~ AUTH COST $238000~ ~MOCO W.!, 62.5000~ gAYS F~OM SPUD 1560 OPERATION'5:' TD 11600 FT COSTS: CU~ WELL $382171 CH~ON TIME DISTRIBUTION 24.00 - OTMER~ MGS 17595 27~ MIDDEE GRN3 SHOAL¢ P~RKER '152~ AMOCO PRODUC'TIDN'~' ....... FLOC 8~6156-C1-6~ API 507332036800~ AUTH TD 11600~ AUTH COST $238000~ aMOCO W.I. 62.5000~ 9~Y5 FROM SPUD ISGI OPERAT'~ONS:' TO- 1160C, :'T ................... COSTS: CU~ WELL $3821~1 RE~ARKS: 6 HR TEST: 3~1 B~L FLUID; BSEW 56.7&; ~CCD 365; GOR 607; GRaViTY 3~.3: SPOPD iGC2 ,~ 3~25 PSf: FLUID LEVEL 16~2 FT CHRON TIME 'DISTPI~UT~ON (HRS): ....................... 2~.00 - OTHER~ PUMPING - TESTING n*-NV~,~ RE~IP..N '"~::: ~NC~DR~GE gISTRI[CT -':::~..- Ol/Oq/,5~ =.'=---*=;: P.,~GE i'~ a~3C,.O W.I. 62.5000t SAYS FROM SPUD 1562. OPERaTiONS: TD 116C0 COSTS: CU~ WELL $382171 CHRON TIME 'DI'STR'IBUT'ION 2~.90 - OTHER~ PUMPING- NO GU~GE; FLUID LEVEL 1'783 FT MSS l.'tSg~ 2-I, ~qICDLE Gm, ND SHOAL, P~,RKER 152, AMOCO PRODUCTION, ., -,... ,-.: ..:: ~ ...,: ...... ~;.... :,': .~.. ~ -'- .'- -,- :.'~ :,': ~: :.'=. ¢.: ~ ~ ~. ~ ~ ~: ~: :,': '- .1= .-~ ..... ~--'- ...... ~:.': FLOC aq61'~6-~01'6~ ~P I' '507~12036a00~ ~UI'H:"'TD '1'1600~ ~MOCO W.I..62'5000,DRYS FROM S~UD 156'3 OPERAT'IONS: TD !.1600 F'T COSTS: CUN ~ELL $3a2171 2~.00 - OTHE~ PUMPING - NO ,']U~GE; FLU~ LEVEL 1721 FT MGS 17595 27, MIDDLE GRND SHOAL, P~RKER 152, AMOCO PRODUCTION, FLOC Sqnl~G-Ct-6, ~°I 53~3]20~$,geO, ~UTH ~D 11600*"~UTH COST ~OCO N,I, 62,50e0~ DAYS F~OM SPUC 156~ OPERATIONS: TD 11600 PT COSTS: CUM WELL $3~2171 R~,RRKS': '5 HR TEST: B.~L FLUID 336; GTY 3~,'5; ~SW '59.0~ MC~D:"323; GOR 585; LIFT IN 16,74 2 3425 PSI; FL iT8~ FT CHRON TZ~E DISTR. ZBUTION (N~.S)': 2~.00 - OTHER, PUMPING - TESiING &MOCO PRODUCTION COi~PANY DAILY DRILLING WIRE DISTRICT DAILY WIRE )E,NVF..R Rt-TGI, ON '~:::::: ANCHORAGE DISTRICT ~:;::::: 01/06/88 -.":~'-.:": PAGE O! vIGS I 7'595 27m MIDDLE GRND SI'-trlAL~ .::-,...,~ -.. ........ ~:: ::: ::: ::: ........ ::: ::: =:: ............. .~: .... - ::: .~;: ...................... ::: .',.. ~ ::: ::: ............... ... ::: ::: ::: ::: .......... .o .........~. ....... .-,:: ........................... .. .................. FLAC 84.6,15~-01-~ APl 507'332036800,~ AUTH TD ! 1000 F'T~ AUTH TVD AUTH COST $2'38000m A~OCO W.l,. 62.5000~ REMARKS: FINAL TEST DATE l/4/88: 605 {30PO; 731 L~WPD; 298 MCFD; GOR GRAVITY 34.2; BPOPD 1663 BElL @ 34,80 PSI; FLUID LEVEL 1808 FT FROM SURFACE OPT CHRON TI BE DJ STRIBUTION J HRSJ: 2~.00 - OTHER~ PUMPING NO GAUGE CURRENT WELL ACTIVITY-CCINIPLT-OE, G~ [)ATE 11/26/87 ~NI') OF JOB SUmmARY: OPER COMPLETED DATE ! 1/26/87 FINAL REPORT END OF REPORT Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-562-2147 W. G. Smith District Manager November 16, 1987 Alaska Oil and Gas ConservatiOn Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' Mr. C. V. Chatterton, Chairman File' FEW-145-WF Gentlemen' Application for Sundry Approval MGS 17595 Well No. 27 Platform Baker, Cook Inlet, Alaska Attached in triplicate for your approval is State of Alaska Form 10-403, Application for Sundry Approval, for work Amoco proposes on MGS 17595 Well No. 27. We plan to add pay in the "BCD" Oil Pool and commingle production from these zones with existing production from the "EFG" Oil Pool. We received administrative approval to commingle these two oil pools in the Commission's letter to us dated October 30, 1987. Please direct any questions regarding this application to Tom Bonenberger at 562-2147. Very truly yours, W o G. Smith District Manager TWB/dds Attachments RECEI /ED NOV 1 6 Alaska Oil & Gas Cons. C0mmiss[0~ Anchorage ~.-~--.... STATE OF ALASKA ---'---r., AL , OIL AND GAS CONSERVATION CC '3SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate I,~ Other 2. Name of Operator Amoco Production Compa_ny 3. Address P.O. Box 100779, Anchoraqe, A.]aska 99510 4. Location of wen at surface Leg 2, Slot 5, MGS Platform Baker 1985' FNL, 584' FWL, Sec 31, TgN, R12W, S.M. 5. Datum elevation (DF or KB) 79,4' _1<.15 6. Unit or Property name Middle Ground Shoal 7. Well number 27 feet At top of productive interval At effective depth At totaldepth 11,600' MD, 9,258' .TVD, 4,112" Sec 30. TgN, R12W, S.M. 8. Permit number FSL, 1,982' FWL 9. APl number 50-- 733-20368 10. Pool MGS "BCD" & "EFG" 11. Present well condition summary Total depth: measured true vertical 11,600 feet 9,258 feet Plugs (measured) 11,003', 11,137' Effective depth: measured 11,003 true vertical 8,669 feet Junk (measured) feet Casing Length Structural Conductor Surface Intermediate 3,407 Production 8,844 Liner 3,002 Perforation depth: measured Size Cemented Measured depth True Vertical depth 13 3/8" 3070 sx 3,40'7 2,954 9 5/8" 1400 sx 8,844 6,763 7" 925 sx 8,590-11,592 6,568 - 9,250 9,968 - 10,980 true vertical 7,707 - 8,647 RECEIVED NOY ] 6 l~a/ Tubing (size, grade and measured depth) Dual 3½" N-80 buttress wi th hydraulic 1 ift bottomhol e asseml~t~,ka 0ii & Bas Cons. C0mmissi0r~ Packers and SSSV (type and measured depth) Anchorage None 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation November 16, 1987 14. If proposal was verbally approved Name of approver Russ Dougl as Date approved 11-16-87 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Commission Use Only Date11-16-87 Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test E~ Location clearance Approved Copy Returned Approve. dby ~//1t ~, ~~ ''cOm.m.issiOne! Form 10-403 Rev 124-85 1 Approval No.....,~ ~- by order of the commission Date Submit in triplicate DETAILED OPERATIONS PROGRAM 1. Kill well with diesel. 2. Set back-pressure valves. Nipple down tree, nipple up BOP's and pressure test. Pull back-pressure valves. 3. Pull tubing. 4. Run CBL-VDL-GR in 9 5/8-inch casing from 8,590' to cement top. 5. Complete well with dual tubing strings and hydraulic lift bottomhole assembly. Tubing-conveyed perforating guns will be placed below the bottomhole assembly. 6. Set back-pressure valves. Nipple down BOP's, nipple up tree and pressure test. Pull back-pressure valves. 7. Pump well down to perforate under-balanced. 8. Drop bar to perforate. 9. Return well to production. RECEIVED NOV ] 6 z o/ Alaska 011 & Gas Cons. Commissk~n Anchorage MOV, 13 '87 17:2::3 RMOCO PROD D£MV ---- * "~'~ Amoco Production Compa , ENGINEERING CHART ! Appel · .~3GSz,I. ; RECEIYEI) NOV ] 6 ~)o/ 011 & Gas gons. gomrnissi'~:'~; Anchorage MOV 13 '87 17:23 RMOCO PROD DEMV .- ' ~'---"' Amoco [>rOductio,~ Compa ENGINEERING CHART SUBJECT 'F j / f ii t, 3 $ ^ltl:;n I "RECEIlIEI) NOV '1 fl t~b / ,. ,-~,,~ Oil & 6a~ Cons. c0mmissk~;, ,',',.r.a.~.~-Anchorage .~.15~~ I ,. .,? :.7 ~' Amoco Production Con. NO. . . ' ' _ _]___!_ _-J ' ---- - ~----'---" ~':----' . /qYDRIL / L ANNDLfllv, BOP .5-000 ,r /:'/Z/. L iA/Z2 ' R!\]-~ -TXIT [ l-~U 0 -r~o ,._ ctto~:c. o! RECEIVED ~_ lO JUL'*5 _sOB Alaska Oil & Gas Cons. Commission Anchorage October 30, 1987~ ':A D M I N I S'T R A T I V E APPROVAL TelecoPy Nb. (907) 276-7562 N O. 44.40', Re ! Application to commingle ProHUc'tion from the MOS "BCD" Pools with production from the MGS "EFG" Oil Pools in the MGS 17595 well ~27, Amoco Production Company, operator. W G Smith District Manager ~' Amoco Production Company P O Box 100779 Anchorage, AK 99510 Dear Mr Smith: ~ · On October 26, 1987 the referenced application was received which stated that the request for approval to commingle the BC .. Oil Pools with the "EFG" Oil Pools ±s based upon the necessity of using hydraulic pump lift equipment. The "BCD" Oil Pools and "EFG" Oil Pools both require artificial lift in order to be. produced to the surface. The installation of hydraulic pump . equipment to produce the "EFG" Oil Pools precludes the possi- bility of a dual completion because of the restrictions imposed by the'casing and pump sizes. In the event that approval to commingle is not given, one Of the pool groups would be shut in in favor of producing the more prolific oil pool group. No restrictions which require that the two pool groups be mechanically segregated in the wellbore are required. The Commission hereby authorizes the commingling of the referenced production pursuant to Rule 6 of Conservation Order No. 44. Sincerely, W W Barnwe Commis s loner jo/3 .AA44 W. G. Smith ~istrict Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 July 22, 1985 File' TJZ-271-WF Mr. C.V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, A1 aska 99501 Dear Sir' Subsequent Sundry Notice Middle Ground Shoal 17595, Well No. 27 Platform Baker, Cook Inlet, Alaska Attached in duplicate for your approval is State of Alaska Form 10-403, Sundry Notices and Reports on Wells, concerning additional perforations recently shot on MGS 17595 Well No. 27. Very truly yours, W.G. S~th Di stri ct Manager Attachment JCB/kmh RECEIVED ?, ~ G,~s Cons, Commissio~ f -- STATE OF ALASKA ALASKA,_ __ AND GAS CONSERVATION C,_ ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL3[gl: OTHER [] 2. Name o~ Operator~ , , . 7. Permit No. ~moco ~roauctlon Company 83-116 8. APl Number 3. Addressp. 0. BOX100779, Anchorage, Alaska 99510 50Z33-20368 4. Location of Well 9. Unit or Lease Name Middle Ground Shoal Leg 2, Slot 5, MGS Platform Baker 1985' FNL, 584' FWL, Sec. 31, T9N, R12W, S.M. 5. Elevatiq~n~in ~eetc~ndicate KB, DF, etc.) / ~.~1' 12. 10. Well Number 27 11. Field and Pool Middle G. round Shoal Field Lower Kenai Conglomerate Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] ' Stimulation Repair Well [] Change Plans [] RePairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) ~ Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On July 8, 1985 Amoco Production Company' le e Circulated pump out of hole and pulled standing valve. Rigged up electric wireline lubricator. Perforated the interval 9,968'-10,052' with 4 JSPF, 0.34" diamater holes. Rigged down the lubricator and returned the well to production. RECFiVED 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission Conditions of Approval, if any: OJJ 2~ (-_;.'-is C'(~;,,s. Date 07/22/85 By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 July 3, 1985 File: TJZ-247-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission -3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent MGS 17595 Well No. 27 Platform Baker, Cook Inlet, Alaska Attached in triplicate for your approva-1 is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, for MGS 17595 Well No. 27. Amoco proposes to perforate additional pay in the subject well. Very truly yours, W. R. Hal vorson Acting District Manager Attachments JCB/dds RECEIVED JUL 0 8,~ 41aska 0il & P~as Col'iS. Corrll]lissiort Anchorage STATE OF ALASKA ' ALASKA UIL AND GAS CONSERVATION CUMMISSION SUNDRY HOTIC"=S AND REPORTS ON WELLS 1. DRILLING WE'LL [] COMPLETED WELL J~ 2. Name of Operator 7. Permit No. Amoco Production Compan.v 83-116 3. Address 8. APl Number P. 0. Box 100779, Anchorage, Alaska 99510 50- 733-20368 OTHER [] 4. Location of Well Leg 2, Slot 5, Middle Ground Shoal Platform Baker 1,985' FNL, 584' FWL, Sec. 31, TgN, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 79.4' KB 12. I 6 . Lease Designation and Serial No. ADL 17595 9. Unit or Lease Name Middle Ground Shoal 10. Well Number 27 11. Field and Pool Middle Ground Shoal Heml ock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). In July, 1985, Amoco Production Company proposes to: 1. Rig up a wireline lubricator and pressure test. 2. Perforate the interval 9,968 - 10,052 feet (Hemlock) with 4JSPF, 0.5-inches diameter. 3. Rig down the lubricator and return the well to production. ~sequent Wort: l~orte~ RECEIVED JUL 0 8 Alaska 0il ~ ~.'~$ "',~. Commission 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed The space below for Commission use Conditions of Approval, if any: Tit,~cting District Manager Anchorage Date07/03/85 Returned Approved by .. BY ~R¥ W. KgGLER By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate RE RETAIN THIS SECTION FOR YOUR RECORDS MGS 17595 WELL #27 RUN 2 (AMOCO) D I PLOG 1 PRINTS NEG. 1 SEPIA CN/CDL 5" 1 PRINTS NEG. 1 SEPIA CDL 5'-' 1 PRINTS NEG. 1 SEPIA D IFL 5" LOGR. 1 PRINTS NEG. 1 SEPIA D IFL 2&5" LIN. 1 1 ABOVE RECEIVED FROM: ~/"'~" ,. I VED :~ ATT: L & GAS C0.~R SIGNED (C.V. CHATTERTON) L,,"--.' .... ""'~ '- ' ,'-~A~E~_i;, a I:~.~s ConS. l~m.mis, sion RETAIN THIS SECTION FOR YOUR RECORDS RE MGS 17595 WELL #27 AMOCO DIFL/GR 5" [OGR. 1 PRINTS 0 NEG. 1 SEPIA DIFL/GR 5" LIN. ~ 1 PRINTS 0 NEG. 1 SEPIA DIFL/GR 5" LIN. 1 PRINTS 0 NEG. 1 SEPIA DIPLOG 1 PRINTS 0 NEG. 1 SEPIA ABOVE RECEIVED FROM: DRESS R SIGNED DATE Alaska 0il & Gas , · Anchorage _ Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 W. G. Smith District Manager January 15, 1985 File' TJZ-O23-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Si r: Well Completion Report Middle Ground Shoal 17595, Well No. 27 Platform Baker, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-407, Well Completion or Recompletion Report and Log, for the subject well. A directional survey and a well history are also enclosed for your information. The electric logs are being sent separately. Very truly yours, W. G. Smith District Manager Attachments JCB/pmg RECE V£D A~aS~(a Oi~ & Gas Cons. Commissio~ Anchorage ' ~ STATE OF ALASKA '" ALASKf-~,.._ AND GAS CONSERVATION CC,,-...;ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well :. OIL []~' GAS [] SUSPENDED [--I. ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Amoco Production Company 83-116 3. Address 8. APl Number P.O. Box 100779, Anchorage, Alaska 99510 50-733-20368 4. Location of w~.ll at surface ~l~-'l~ 9. Unit or Lease Name State Eeq ,2, STo~ 5,,lqGS Platform Baker -~oNs 1985 FN£, 584 FWL, Sec. 31, T9N, R12W, S.M. [ VE~F~D i Middle Ground Shoal 17595 At Top ProduCing Interval I. Surf.__~y, i 10. Well Number ' .~~. 27 At rotal Depth 11,600' MD, 9258.' TVD, 4112' FSL, 1982' 30 11. Field and Pool 'T9N, R12W, S.M. Middle Ground Shoal Field _5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Lower Kena i Conglomerate 79.4' KBt 'ADL 17595 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116-N°'ofC°mpletions 9-19-83 1-3-84 12-15-84, compl etedl 102 feet MSLI 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 11,600 MD, 9258TVD 11,070MD,8735 TVD YES'[~ NOI-] N/A feetMD None 22. Type Electric or Other Logs Run DIFL-SP-GR; CNL-CDL-GR-Caliper; DIPLOG 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13.375 54.b,bt, 'K-55,N'-80 . 0 3407 17.5 2500 sx class ':G" + 58 " 570 sx Top Job' 9.625 ~_0_,43,5, -S-95 0 8844 12.25 1400 sx class "G" ~'-'7, '53.5 7 29, 35 S-95 8590 11,592 8.5 925 sx' class "G" . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD -interv'al, size and number) ' SI'ZE DEPTH SET (MD) PACKER SET (MD) 1'0,932'-10,938' MD(8599'-8605.'TVD) 24 shOts gu~l 3.5" 8554' N/A 10,954'-10,960'MD (8621'-9627'TVD) 24"~hots ~ 10,974'-10,980'MD (8641'-8647'-TVD) 24 s'hoi~e 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4 SPF, 0 5 inch '. SEE' ATTACHMENT : 27. PRODUCTION TEST Date First.Production I Method of Operation (Flowing, gas lift, etc:) I 12/05/84 -Hvdraulic Lifl Date of Tes~ 'Hours Tested PRODUCTION~FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 12/15/84. · : 12 .hour TESTPERIODI~. 46 8.2 0 N/A 178 Flow T~b!ng' : casing PreSsure CALCULATED OIL-B.BL GAS-MCF WA'iLER-BBL OIL GRAV TYtAPI (corr) 'Pre. ss.75': :.. 69 ~' 24'ILIOURRATE [~ 92 16.4. 0 35.5 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 'RECEIVED .- .NONE ~.:. . _ ..iAt',i 1 ' : Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLC)GIC 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. Lower Kenai Conglomerate Zone G-1 9704' 7473' Zone G-2 9916' 7661' Zone G-3 10,136' 7857' Zone G-4 10,400' 8095' Zone G-5 10,762' 8435' . 31. LIST OF ATTACHMENTS Directional Log Suite (sent separately); Detail .'to section 26; Chronological History; Survey- 32. I hbreby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This_ form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' ClaSsification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection .for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage 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". ATTACHMENT Detail to Section 26 MGS 17595 Well No. 27 26. PERFORATIONS 01/14/84 - 01/15/84 MD 10,760' - 10,874' 10,992' - 11,114' TVD Net Feet Size 8433' - 8543' 114' 0.32" 8658' - 8778' 122' 0.32" Total 236' 4 JSPF, total of 944 shots 26. ACID JOB 03/29/84 - 03/30/84 Interval 10,760' - 10,874' MD; 10,992' - 11,114' MD Volume Fluid Type Maximum Pressure 1000 gal. 10% HCL 3500 psi 2000 gal. 6% HCL, 1½% HF 4000 psi 10.00 gal. 10% HCL 3750 psi 26. PERFORATIONS 04/24/84 MD TVD Net Feet 10,758' - 11,058' 8431' - 8722' 300 11,087' - 11,115' 8750' - 8779' 28 Total 328' 4JSPF, total of 1,312 shots. Size 0.5" 0.5" Fyi,. ,i i 8 1985 'qlaska 0il ~Gas COns. C°;nrnission snchorage ATTACHMENT Detail to Section 26 MGS 17595 Well No. 27 26. CEMENT SQUEEZE 10/17/84 - 10/18/84 Interval 10,758' - 11,115' MD Vo 1 ume 5 3/4 BBL F1 uid Type Class "G" Cement Maximum Pressure 3200 psi 26. PERFORATIONS 10/20/84 MD TVD Net Feet Size _ 10,932' - 10,940' 8599' - 8605' 6' .5" 10,954' - 10,960' 8621' - 8627' 6' .5" 10,974' - 10,980' 8641' - 8647' 6' .5" Total 18' 4 JSPF, total of 72 shots 26. FRACTURE STIMULATION 11/28/84 - 11/30/84 Interval 10,932' - 10,940'; 10,954' - 10,960'; 10,974' - 10,980'MD Vo 1 ume Fluid Type 420 BBL Cross-linked Gel l 7200 psi wi th 14,000 lb. ceramic proppant Maximum Pressure RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ATTACHMENT Chronological History 09/19/83 through 09/20/83 09/04/83 through 09/22/83 09/22/83 09/24/83 through 09/28/83 09/28/83 through 09/30/83 10/01/83 through 10/14/83 10/15/83 through 10/17/83 10/17/83 through 10/20/83 10/21/83 10/22/83 through 10/31/83 11/01/83 11/02/83 through 11/09/83 11/10/83 through 11/11/83 11/12/83 through 11/14/83 11/14/83 through 11/23/83 Spud Well. Dyna Drill to 343'. Drilled 343' - 1047' Dynadrilled 740' - 1047' Drilled 1047' - 3420' Run 13 3/8" casing and cement Drilled 3420' - 6875' Dynadrilled 6875' - 7161' Drilled 7161' - 7805' Circulate hole Drilled 7805' - 8956' Drilled to 8964'. During reaming 7838 - 7901', rotary table failed. Started to trip out of hole. Bit stuck at 7830'. Jar and work stuck pipe. Back off at 7498' [332' fish in hole]. Set cement plug from 7498 - 7277' and polished off at 7303' [Side track depth.] Dynadrill 7303 - 7383'. Drilled from 7383 - 8973' RECEIVED ,iA?,.! 1 8 985 Alaska Oil & Gas Cons. 6ommission Anchorag8 ATTACHMENT Chronological Histor3, 11/24/83 11/25/83 through 11/30/83 12/01/83 through 12/04/83 12/04/83 12/05/83 through 12/06/83 12/06/83 12/07/83 12/07/83 12/09/83 12/10/83 12/11/83 through 12/12/83 12/12/83 through 12/19 12/19/83 through 12/20/83 12/20/83 through 12/29/83 12/29/83 12/30/83 01/01/84 through 01/02/84 On trip out, lost bit and stabilizer [7' fish in hole]. Attempt to fish and pushed to bottom. Top of fish at 8959'. Conditioning hole to run 9 5/8" casing. Conditioned hole. Ran and cemented 9 5/8" casing to 8844' MD. Drilled out float shoe to 8860' MD. Ran leak off test to 13.2 ppg equivalent mud weight. Clean out to fish at 8959'. Set cement plug from 8959 - 8846' and polished off at 8863' [second side track depth.] Dynadrill 8863 - 8935' Drilled 8935 - 9179' Dynadrill correction run 9179 - 9239'. Drilled 9239 - 9417' Dynadrill correction run 9417 - 9451'. Drilled 8451 - 10,407' Logging Drilled 10,407 - 11, 367' Logging Drilled 11,367 - 11,464' Drilled 11,464 - 11,594' RECEIVED Oil & f,.'~}s (~,]~as, C~;nimission 01/03/84 through 01/04/84 01/05/84 through 01/08/84 01/09/84 01/10/84 01/11/84 through 01/13/84 01/14/84 01/15/84 01/16/84 01/17/84 through 01/19/84 01/20/84 through 01/23/84 01/24/84 through 01/30/84 01/31/84 02/01/84 through 02/23/84 02/24/84 02/25/84 through 02/29/84 03/01/84 through 03/26/84 03/27/84 through 03/28/84 03/29/84 through 03/30/84 ATTACHMENT Chronological Histor~v Drilled 11,594' - 11,600'. Ran 7" casing to 11,592' and cemented. Drill cement from 5569' - 8340', pressure test liner lap. Run GR/CCL log Run Gyroscopic survey log Run dual tubing completion Perforate 10,992' - 11,114' Perforate 10,760' - 10,874', 10,900' - 1Q,992' Run pressure gradient survey Pump testing with Kobe pump Shut-in for pressure buildup Pumping testing with Kobe pump Shut-in for pressure build up Shut-in for pressure build up Open for fl ow Shut-in for pressure build up Shut-in for pressure build up Well open to fl ow Acidize well RECEivED 4/aska 0il a Gas Oons. Anchorage Commission ATTACHMENT Chronological History 03/31/84 04/01/84 through 04/13/84 04/14/84 through 04/19/84 04/20/84 through 04/21/84 04/22/84 through 04/23/84 04/24/84 04/25/84 through 04/30/84 05/01/84 through 05/09/84 05/10/84 through 05/23/84 05/24/84 through 05/31/84 06/01/84 through 06/30/84 07/01/84 through 07/13/84 07/14/84 through 07/23/84 07/24/84 through 07/31/84 08/01/84 through 08/31/84 09/01/84 through 09/30/84 Pump testing with Kobe pump Pump testing with Kobe pump Shut-in for pressure build up Pull dual string completion Run dual string completion Perforate 10,758' - 11,058', 11,087' - 11,115'. Pump testing with Kobe pump Pump testing with Kobe pump. Shut-in for pressure build up Open for fl ow Open for flow Open for fl ow Pump testing with Kobe pump. Open for flow Open for fl ow Open for fl ow Oil & Gas Cons. Commission ATTACHMENT Chronological History 10/01/84 through 10/02/84 10/03/84 through 10/06/84 10/07/84 through 10/12/84 10/13/84 through 10/16/84 10/17/84 through 10/18/84 10/19/84 10/20/84 10/21/84 10/22/84 10/23/84 10/24/84 through 10/30/84 11/01/84 through 11/28/84 11/28/84 through Open for fl ow Pull production equipment and RIH w/open ended tubing. Well shut-in Run pre-frac step rate test on well Well shut-in Drill cement 10,722' - 11,070' Perforate 10,932' - 10,938'; 10,954' - 10,960' 10,974' - 10,980' Run temperature survey 10,100' - 11,070' Run data frac on well. Run temperature survey 10,100' - 11,070' Back fl ow well Pull frac tubing. RIH w/open ended tubing. Suspended operations Suspended operations Fracture stimulated well with 13,500 gallons YF4 "PSD" treating fluid, 14,000 pounds 20-40 interprop, and 4,150 gallons flush into perforations. 10,932' - 10,938'; 10,954' - 10,960'; - ['i.. ii. Ai~choraga 12/01/84 12/02/84 12/03/84 through 12/04/84 12/05/84 through 12/15/84 ATTACHMENT Chronological History. Back fl ow well after frac. Circulate well. Pull frac tubing Run dual string completion Pump test with hydraulic pump. RECEIVED ,~ & [',a,~ Cons, Commission AMOC:C~ PRODUCTION COMPANY MG'._--; 17595~ WELL NO: 27~ GM'.E; ._lOB NO: A0184-G('~225 BAKER PLATFORM, MIDDLE GROUND SHOALL:;~ COOK INI._ET, ALASKA GMS~ 0-11600 MD, SURVE"YOR: D PEFFERKORN, DATE RI.JN: 10-dAN-:E:4 G Y R ~] N ~-~: ._~ .-.'-' 4 / '-'.-,~'~. =, CAMERA NO ' I /'.,") =; / 1 ".'-' "-.'~ /., 0- 9 0 B E ~q A / I_1 N ~]: 14 7 8 / 1 .=;'.':'":' FORESIGHT: SHELL F'LATFORM A SO'F.z 42:31W SURVEY TAKEN FROM ROTARY 'TABLE VERTICAL SEC:TION CALCULATED IN PLANE OF F'ROPOSAL DIRECTION: N 12 DE~'Z~. :2:8 MIN. E RECORrJ Eft:'-' SI. IRVEY RADILI?-; OF CURVATURE METHOD AMOCO F'RCIDUCTION COMF'ANY COMPUTATION PAGE NO. MOS 17575, WELL NO: 27, GM'.3 .JOB NO: A01:::4-C~0'---.'25 TIME DATE '~;" BAKER PLATFORM, MIDDLE C4RCil .... IND SHOAL'.:;, COOK INLET, ALA~:;KA 1~.'-"' ¢~9: 14. 1:?-dAN-84 TRUF-E MEA'.=;URETI 1]RIFT DR IF:'r C:OUR3E VERTICAL VERTICAL R E C T A N G U L A R C: L 0 8 U R E DOGLE( ~ ' D I :];TANCE D I RECT I ON '.:;EVER I ] DEPTH ANGLE DIRECTION LENGTH [EFTH '.=;EF:TION C ~-~ ~] R D I N A T E c. FEET D M D FEET FEET FEET FEET FEET 1] M DG/100t 0.. 0 0 0 0. 0.00 O. 00 100. 0 0 0 100. 100.00 0.00 200. 0 0 0 100. 200. O0 O. 00 300. 1 0 N 21 E 1 O0. 299. S~'F~ 0.8/=. 400. i 30 N 28 E 100. 399. '.'.:~7 3.00 500. .1 30 N 26 E 100. 499.94 5.5:3 600. 1 15 N 24 E 100. 599.'?1 7.8:3 700. 1 30 N 18 E 10C~. 6'.=.~?/. 88 10.25 800. 3 15 N 14 E 100. 7'~':.'-~. 79 14.3:3 ~:~00. 6 0 N 12 E: 100. :]:'.:.~?.~. 45 22.45 5.13 N 2.41 E 7.30 N 3.42 E ?.54 N '4.28 E 13.53 N 5.42 E 1 .~.o ..:,,., N 7,23 E 5.67 N 25 7 El 8.06 N 25 5 E 10.46 N 24 '.:/ E 14.57 N 21 50 E 22.57 N 1:E: 42 E O. 00 0.00 0. O0 1.00 0.52 ,. (.. 0, .-,r=. 0.2? 1,7/..:, 2,75 1000. 9 0 N 13 E 100. ?78.59 35.50 1100. 11 15 N 11 E 100. 1097.02 53.07 1200. 12 :]:0 N 11 E 100. 1194.88 73.64 1300. 15 30 N 10 E 100. 1291.?0 97.81 1400. 20 0 N 10 E 100. 1387.11 128.26 :34,. 12 N ' .1.0.06 E 51.._.'~'~" N.- 1.3.-71 E 71..52 N" E 95.30 N 22~05 E 25. :3':..' N'" 27 '. 34 E 35.57 N 16 25 E 53.12 N 14 58 E 7:::.66 N 13 51 E 97.82 N 1:]: 2 E 128.26 N 12 18 E :3.00 2.28 1.25 3.01 4.50 1500. 24 30 N 10 E 100. 1479.65 I66.08 1600. 2? :]:0 N 10 E 100. 156:s:.72 211.41 1700. :31 0 N 11 E 100. 1655.10 261.75 1800. :]:2 15 N 14 E 100. 1740.25 314.1:3 ,--.- ,--,.-, 1900. c:'/ 4.~._ N 1 o" E 100 . 1 ,:,.. 4 . _ 367. '.70 162.60 N 33.91 E 207.29 N 41.79 E 256.6:2 N 50.$~7 E 308.01 N 62.32 E 360.25 N 74.6:7 E 166.07 N 11 4.7 E 211.46 N 11 24 E 261. ,_,¢":'._, N I 1 14. E 314.25 N 11 26 E .... :-=:67.'=-.~5 N 11 44 E 4.50 5.00 1.58 2.01 ( )3 2000. 33 30 N 13 E 100. 1908.33 422.55 2100. 34 15 N 12 E 100. 1991.36 4-78.29 2200. 35 0 N 13 E 100. 2073.65 535.10 2300. 35 45 N 14 E 100. 2155.18 · 5S~2.99 2400. 37 0 N 14 E 100. 2235.70 652.28 413.50 N 87. 16 E 4.67 '.--.~ 1 N ;; -,.,',., E 52:3. :-":9 N 111.52 E 579.68 N 125.03 E 637.22 N 137.38 E 422.58 N 11 54 E 476:. 32 N 11 58 E · ~.~, 1:3 N 1'--.' ~ E · _ :=,._ , .~. .-- 59:::.01 N 12 10 E 652.29 N 12 20 E 0.75 0.93 0.94 0.95 1.25 2500. 40 30 N 14 E 100. 2313.67 714.84 2600. 43 30 N 1:3 E 100. 2:387.9:3 781.74 2700. 44 0 N 13 E 100. 2460.22 850.8? 2800. 44:30 N 13 E 100. 25:31.85 920.67 2900. 43 30 N 14 E 100. 2603.78 '~'F/O. 13 .,. 697.'.=~5 N 154.52 E 763.00 N 170. 14 E :]:30.38 N 185.70 E 898.37 N 201.:39 E . ~ ?65..92 N 217.61 E 714.8.5 N 1'," ,.. E 3 50 7:31.74 N 12 34 E :3.07 850.8'.=.~ N 12:2:6 E 0.50 9. 2(). · 67 N 1 .,_'7' ._,_,':~ o E 0 .50 . '?'.=/0, 1:3 N 1 '-'.-' 42 E 1,22 AMOCO PRODUCTION COMF'ANY MGS 17595, WELL NO: 27, GM'.E; ,JOB NO: AO16:4-L,U...~'=.:. BAKER PLATFORM, MIDDLE GROUND '.:-;HOALS, COOK INLET, ALASKA C 0 M P U T A T I 0 N T I ME lqATE 12:09 14 i~-,_AN-,:'.4 TRUE MEASURED T]R IFT DRIFT CCfl_IR:-:E, VERTICAL VERTICAL R E E: T A N E4 U L A R fi'_: L Fi S U R E BOGLE( ........ · =,EVER I 'l .=.TAN _.E D I RECT I ON '-' " DEPTH ANGLE DIRECTION LENGTH DEPTH ::;ECTIF~N C 0 ri R D I N A T E '=' DI'-' P FEET D M D FEET FEET FEET FEE1. ' FEET D M [iG'~"i 00F :3000. 43 15 N 14 E 100. 2676.47 1058.78 3100. 47 30 N 15 E 100. 274/=,.70 1129.90 3200. 48 45 N 15 E 100. 2813.45 1204.29 33¢)0. 47 45 N 15 E 100. 2E:80.03 1278.8:'-: 3400. 48 30 N 15 E 100. 2'?46.78 1353.23 E:500. 47 0 N 15 E 10C). :2:014.02 14. 27.19 :2:600. 46 45 N 15 E 100. 3082.38 150c). 11 370C~. 4/_-, 0 N 15 E 10¢~. :3151. :::7 1572.44 .3:800. 46 4.5 N 15 E lO0. :3220. :'-:6 1/-...44.76 3900. 45 0 N 14 E 100. 3289.98 1716.5£) 1388.85 N 1459.34 N 1529,. 26 N 1599.18 N 16/=,E: ·/=,8 N 329. · ~ · 0._ E 347.94 E :'::/=;6.67 E · :,,=,..,. 41 E 403.38 E ~ ti'=,':'. 78 N 12 47 E 0 ~._°.$ 11~...",'-?. 9. 1 N 12 ..... E 4 ~ .3:1 1.2~ 1 · 00 0.75 1427.29 N 1.3:20 E 1..~0 1 .:;(')0 '-' ''= N 13 2.'--i E 0 "' 15'72.61 N 1:3 2'? E 0.75 1644.97 N 15::3:3 E 0.7.5 171/-.., 74 N 1:3 '"'~' .-,._, E I ,~,o 4000· 45 45 N 14 E 100. 3360.23 1787.65 4100, 44 45 N 14 E 100. 3430.63 1858.65 4200. 46 0 N 14 E 100. 3500.87 1~29.80 4.3:00. 46 4.5 N 14 E 100. 35/=.9.87 2002. 17 4400. 46 15 N 15 E 100. 3638.70 2074.67 1737.74 N 4.,,..¢ .. 60 E 1,:,.)6 64 N 437"'78 E 1~'7.~, 7¢) N 455 O0 E ?]4~,.94 N 472.51 E 2016. 16 N 4'.-.70./=,7 E 1787.'?1 N 1:3 :--'.'6 E 1858.9.'_'-': N 1:3 37 E 1930. 10 N 13:3:9 E 2(])02. 4-::: N 1:3 39 E 2075.01 N 13 41 E 0.75 :1.. 00 0.75 0.8:3 4500. 45 C) N 15 E 100. 3708.64 214.6.08 4/~,(')('). 4.5 4.5 N 16 E 1 (] c') 3778. ':' '=' '-" ..17.° 16 4700. 42 3¢) N 16 E 100. 3850./-..,5 228/_-.. 66 4800. 43 0 N 16 E 100. 3924.09 2:354.42 4?7¢)0. 44 30 N 16 E 100. 3':';96.32 242.3:. 45 2085.20 N 2153.79 N 2220.7£) N 2285.95 N 2:352.43 N 509.17 'E 2146.47 N 1:3 4. :3 E · _~...,.,'::"=', 19 E.,.,_'s".-' 17 .61 N 1:3 4. 7 E 547.38 E 2287.17 N 1:3 51 E ._~ A_ ._./-, 09 E 2:355 .0 C) N 1._, '~- 55 E .~85.15 E- 2424,11 N 1.3:58 E 1.25 1.0:_'-: · .:.. ',"5 ¢), 5¢) 5000. 47 30 N 17 E 100. 4065.78 2495.21 5100. 48 15 N 18 E 100. 4132.85 2569.11 5200. 48 45 N 18 E 100. 4179.12 2643.6:--: .~,3A0. 50 0 N -'( E 100. 42/-...4.22 2719. 10 5400. 50 0 N 20 E 100. 4328.50 2795.08 2421.39 N 2492.12 N 2563. :35 N ~.,/. ~.,~. .~ ...... lin 2707. lO N 605.58 E ~ ~ 0 :,~7. A E 651.02 E 675.73 E 701.93 E 2495.97 N 14 2 E 2570.00 N 14 E: E 2644.7:3 N 14 15 E 2720.37 N 14 2:3 E 2796.62 N ].4:32 E 3.08 · 1.05 0.50 1.97 · Ci'. 0,0 5500. 52 30 N 19 E 100. 4391.09 2872.50 5600. 54 15 N 19 E 100. 4450.75 2952.26 5700. 54 45 N 20 E 100. 4508.82 :3033.08 5800. 52 30 N 21 E 100. 4568. 12 3112.8:3 5900. 51 0 N 20 E 100. 4/_-.30.03 3190./=.2 27:--:0. /=.0 N 727. ?/=. E 2856.4:3- N '754, 09 E 29.3:3.22 N 781.2/=. E :--:008.63 N :B0'2.46 E 3082.19 N 836'96 E 2874.31 N 14 40 E ~ /=.2 2'254.34 N '14 47"E .... 1','75 :--:C):--:5.49 N 14 55 E 0.96 31.~5.62 N 15 4 E '.F,.39 .3:1 ';;. 5:_. ,_,o 1 N-- 1 ~_ 1 ~.'S, E i'. AMFu-:O PRADUCTION -~ .~, ci ~ ~ . ~ ......... MGS 1~._; ,, WELL NC~: 27 GMS , Ir]B BAKER F'LATFORM, MIDDLE GROUND '.E;HOALS, COOK INLET, ALASKA COMPUTAT I ON T I ME DATE -),=:~. 1.:'=': L .".. 14 12-,_1AN-84 .,. PAGE NO. .~,' MEA.=,URE/ DR I FT DEPTH FEET DR I FT ANGLE D I RECT I ON LENGTH D M D FEET 6000. 49 30 6100. 49 45 6200. 49 4.5 6300. 47 0 6400. 44 0 6500. 4::-: 45 66C)0. 43 30 6700. 41 15 6800. 42 45 6~00. 41 0 TRUE COLIRSE VERTICAL VERTICAL R E C: -r A N G U L A R DEPTH SECTION FEET FEET FEET N 1'2 E 100. N 20 E: 100. N 21 E 100. hi 22 E 100. N 22 E 100. N 23 E l C)O. N 24 E lOC). N 25 E 100. N 25 E 100. N 24 E 100. DOGLEI ,,r. C 0 n R D I N A T E '.=; DISTANC:E DIRE_.TION '.=';EVERI" 4693.97 3266.95 :3154.66 N 862.62 E 4758.75 3342.59 :=:226.47 N 8:98.05 E 4:=:2::-:. 36 3418.19 3297. '.-.76 N '.-.? 14.78 E 4889.78 3492.04 3367.50 N 942. 18 E 4959.86 :2:562.41 '3433.63 N ':.768.89 E C: L 0._,° U R E 5031.95 3:63(]). 69 5104. :34 36'.-.78.44 517:E:. 21 3764.40 5252.52 3:=-:2'F~., 75 5326.98 .3895.07 34-97.66 N ':-;95.41 E 3560.9:E: N 1022.'P2 E :3622.25 N 10.-=,0.87 E 3682.$R) N 1079.15 E :2:74.:2:. 6:3 hi 1106.83 E FEET D M DG/100t :3270.47 N :l.~;._ 1'=:,_ E o'-'Z /. .... :, .I..,. 46N 15 ..-..-,'"":' E .~ z~.:,.-., 4 8 · _-~..~.. N 15 '-" - .:,0 E 3496 :--:2 N 15 :":' E . ._1 i_l :35/_-,7.71 N 15 4.=_; E 36:2:6.54 N 15 5:3 E :3704.94 N 16 2 E 3771.61 N 16 11 E :3837.7!5 N :!.6 20 E · 3.903,8:z: N 1/, 28 E 1 0.80 0.76 2.85 3.00 C,.~4 0.7:2: 1.5¢) 1.87 7000. 39 0 N 21 E 7100. 40 45 N 19 E 7200. 39 0 N 13 E 7300. 38 45 N 12 E 7400. 39 0 N 5 E 100· 5403.58 3758.3~ 100. 5480.32 4021.~7 100. 5557.06 4085.~4 100.~ 5634.~1 4148.70 100. 5712·76 4211.26 :380:3.01 N 11:31.42 E . :'-:~:/-,:-4.25_. .... N · 1153.~,.. E 3'.'.? 24.85 N 1171 "01 E '=' t"]' ~/- ~ .., .......12 N 11,.~4.60 E 404,_°,. 16 N 11':.73.87 E 3967.74 N 16 :34 E 4.)ol.74 N 16:37 E 4095.81 N 16 37 E 4158.42 N 16 33 E 4220.53 N 16 26 E 2.78 2.17 4.22 0.68 4.40 75(:)0. 40 :.]:0 N 4 E 7600. 42 1.5 N 4 E 7700. 44 0 N 4 E 7800. 45 0 N 2 E 7900. 45 45 N 2 E 100. 5789.65 42.:74.56 100. 5864.68 4:3:39.91 100. 5'737.67 4407.4'F; 100. 6008.9'? 4476.59 100. 6C)77;. 24 454/:.. 54 41 I 1.9c). . N. I 198 . oR,_,... E 42:-]::2: .11 N 1 ,_/-, _1..=',_ E 4177. :R':'_ ._. N 120:3.49 E 4:347. -'-'/~ N 1/-._ 4 E 4.-4:. C)2 N 1208 26 E 4414. 59 N 15 5:3 E 4316.02 N 1211.93 E 4482.'.-.74 N 15 41 E 4.387.14. N 1214.41 E .4552·12 N 15 E .63 .75 .75 1- 72 ,)5 8000· 45 0 N 3 E 8100. 44 45 N 3 E 8200. 45 15 N 3 E 8300. 45 0 N 4 E 8400. 44 15 N 4 E 100. 6149.4:.]: 4616.60 100 6220 3.5 46,:.:,.16 100. 6291.06 4755.87 100. 6361.61 4825.83 100· 6432.78 48~5.28 4458.25 N 1217.52 E 4528·71N 1221·21E 4599.32 N 1224.91E 4670.05 N 1229.24 E 4740.12 N 1234.14 E 4621.51 N 15 16 E 46~0.47 N 15 5 E 475?.64 N 14 55 E 482~.12 N 14 45 E 4o,~,:, I~ N 14:36 E ,_, .. l_, · ,_ 1.03 0.25 0.50 0.75 0.75 8500. 44 0 N 4 E 8600. 44 15 N 4 E 8700. 40 0 N 2 E 8800. 37 45 N 2 E 8900. 36 0 N 4 E 100. 6504.57 4964.12 100. 6576.35 5032.95 100. 6650.50 50'F;'F~. 06 1 O0 · 672C-:. :2:5 5160.74 100 ,-,- o .... 4809.58 N 1238.99 E 4879' 03 N 1243.85 E 4946.00 N 1247.36 E 5008.72 N 1249.55 E 5068.63 N 1252.69 E 4966.60 N 14 27 E 0.25 5¢):=:5 ' C)'-.? - N 14 18 E ..... ci. '~...._, = s 100. :s:/=, N 14 9 E 4.. 4/_-, · _.=,162 .2:3 N 14 ('). E 2 · ...._,'-'= 5221. 14 N 1:'~": 5G: ll-E - "' li2 AMI-,_-:FI PREIDLICTTON F:CIMPANY -~c~ ~ _ ~ - _ MG'.--; 1/..,; ._ WELL Nr~: 27 F~M'.S , IF~B NO: AO184-G0225 FAK. ER PLATFORM MIDDLE GRFIIIND SHOALS~ RF,]K INLET ALASKA F':CH'IPLITAT ION F'hGE Nn , z ..... U' · ..... '~. T I ME'] DATE : 12: 09: 14 12 -,J A N-84 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL R E C T A N G U L A R C: L 0 S U R E DOGLE( DEPTH ANGLE DIRECTION LENGTH £EF]H SEr:TIFIN C 0 0 R D I N A T E .~ DISTANC:E DIRECTION '._:;EVERI] FEET D M D F-EET FEET FEET FEET FEET D M riG/100F 9000. 36 30 N 6 E 100. 688:$:. 98 527:_-.'. 50 ? 100. 2:7 15 N 5 E 100. 6968.98 53:5:::_:. 04 9200. 36 0 N 6 E 1£)0. 7049.23 53'.-.-/7.24 9 ........... ::: () (") :--: 6 0 N 9 E 10 (') 71 ~: (') 1.3 ~",~ ~ ...... .=,.=, 77 9400. ._,':'._.=, 1 ._.~'; N 9. E 10 () . 7211 .4:2 ._5 ...=, 1:3 .90 S~500. :5:2 15 N 11 E 100. 7294.55 5569.3'? ?600. 29 0 N 10 E 100. 7380.59 5620.29 9700. 27 15 N S./ E 100. 7468.7:E: 5667. :36 '.'.-~800. 26 45 N 13 E 10£). 7557.88 5712.73 .99/00. 27:5:£) N 13 E 100. 7646.88 575:::. 32 ~.,5"7 o4 E ._.,=._.. F';,,'-, N 1"-: 4.7 E 512'7 54 N 1~ .... , ...... ._ ~.. .... , .-, ,-, ,.:; ~ 51,_,7,._ o ,:'7 N 12/-,.'::__,/',¢')'_ - E ..... :,.:,,=,..'.._, N 1:5:4.1 E 5'.-, 4/-, /-, ?, N 12/-, 9 .o, 1 E ,---.-, c~,-, 00 N 1 '~ :36 E _ ~_ _ . .... · ,_ ._I,.D 7. ':.,. .- · =_;:::¢)4.92 N 1276. ¢~o E 5456.4.5 N 1 :--: ~"'~' ?,:-":62. 45 N 1 ~:'"'",:,6 · 1 (.)~ E' .............. ._,~='z._, 1 .I..._,'='-'~ N 1 2'P E 5417· 15 N 1295.74 E 54/_-.7.23 N 1305.02 E ~1~' 72 ~'1'2 · :, N i ~:~'~ E ,_-_ · ~m mm _ . 5558.28 N 1321.46 E 5602.70 N 1.331.72'E = 6:20 ':::":' · _, . N 13 26 E 56/_-,7,:-':6 N 13 2:4 E · 5713.21 N 1:3 22 E .,=, 7 .~., o ,-~, (- .... , ..... :, .) N 1:5: '.-..".7' E I. 28 O. 96' 1.3'.'.-'~ I. 76 0.75' :3. JO :2:. 29 i · :-::1 1.88 0.75 10000. 27 45 N 13 E 100. 7735.48 5804.6':.'~ 10100. 26 45 N 12 E 100· 7824.38 5850.47 10200. 26 0 N I0 E 100. 7913.97 5894.88 10300. 25 0 N 10 E 100. 8004.23 5937.88 10400. 24 15 N '~ E 100. 8095.14 5979.49 5647.8:3 N 1._4.~. 15 E ?-,/.o.-, 58 N 1~'='''' .... :--'-. ._',._,.~. 06 E 57:36. :1.9 N 1360"54 E 5778.58 N 1368,0'1 E ~.°.19 68 N 1374 o~ E 5805.16 N 13 22 E :::F'i(') '.--.~ 4 N 1 :":: ":'"' E 5895. :3:3 N 13 21 E 59:38.:31 N 13 19 E 5'F, 7'.-.-.'. 88N 13 18 E 0.25 1. 10 1.16 1.00 0.86 1 ¢).~,(] ¢) .... 8 o ~, ....· ,' ..' 15... N E 100 .... 1 ,:, 7 · 01 /-,_ 01 F:._ c,~,._5 10600. 19 30 N 6 E 100. 8280.44 6054.31 10700. 17 15 N 7 E 100. :3375.33 6085.65 10800. 15 15 N 8 E 100. 8471.33 6113.52 10900. 14 15 N 5 E 100. 8568.04 6138.8:3 5858.72 N 1.380.72 E 6£)19.22 N 13 16 E 58';-,4.08 N 1385.07 E 6£)54.63 N 13 1:5: E 5925.40 N 1386:.63 E 6085.94 N 1:5:11 E 5953. 14 N 13~2.29 E 6113.78 N 13 10 E 5978.'43 N 13.95. i7 E 61:39.07 hi 1:':: 8 E 11000. 11 30 N 3 E 100. 8665.51 6160.:36 I 1100. 9 30 N 6 E 100. 87/_-,3.8:--: 6178.90 11200. 9 15 N 4 E 100. 8862.50 6195.04 1 1300 9 0 N i W 100 ~'"' /- ':.' 1 ¢) /, ¢) .... :, ?61.22: _,,. .... I1400. 8 45 N 3 W 100. 9060.04 6225.52 6000.66 N 1396.72 E 6018.82 N 1:5:9:5:. 15 E 6035.05 N 139..o.57 E 6050.?0 N 1399·99 E 6066. !32 N 13':.-~t-.-~. 45 E 6161.07 N 1:5: 6 E ';'.79 617'.--/. 08 N 12: 5 E 2.07 6195.'21 N 1:3 :3 E 0.41 6210 74 N 1:--: 2 E 0 ~''' . · ,_-, ._-, 6225.64 N .... 12' 59~E 0.40 PROdECTED TO 11600 MD 6073.?/1 N 1399.05 E 62.'_-:2.96 N 12 56: E 0.00 6096.7o N 1397. ,--,x /:,254"?C) ..... N-12 55 E ' 0.0(') FINAL CLOSURE -'DIRECTION: D I STANCE: N 1'~,. DE;SR__ .54 M INS 49 SECS E 6,',.4. 90 FEET Su~geste~ form to be insertcd in each "Acnzve" well fo:der to d~.e 'ok for timely ccmpliance with our regulations. Operator, ~el 1 Name and Numker .' Reports and Materials to be received by: ! ..... ~'~ _Required Date Received Remarks _ ·Ccmpletion Reuort Yes Well History Yes /___ /~__ ~. __.,'- ~-- ' · ,. Core Chips '' · / Core Descrip~on Registered Survey Plat :_:.. Inclination Sur~ey /~/-/ ' , Dire~ional ~ey :~, : Drill St~ Test Re~s ,/' - ' STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COi,,.,¢IISSION . "MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIO S -.i l'Drillin~'~e~lQ~e Ground Shoal 17595 Well No. 27 Workover operation [] 2. Name of operator Amoco Production Company 3. Address P. O. Box 100779, AnchOrage, Alaska 99510 4'L°cati°n°fWelleg 2, Slot 5 Middle Ground Shoal Platform at surface Baker 1,985' FNL 584' FWL, Section 31 TgN R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 79.4' KR~ MSL 6. Lease Designation and Serial No. ADL 17595 November 8'4 For the Month of. , 19.__ 7. Permit No. 83-1161 8. APl Number 50- 733-20368 9. Unit or I~s~ N:~te 17595 10. Well No. 27 11. Field and Pool Lower Kenai Conglomerate Middle Ground Shoal Field 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date - 09/19/83 Depth at end of month - 11,600' MD 13. Casing or liner ru.n and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None RECEIVED 6. DST data, perforating data, shows of H2S, miscellaneous data Please See Attachment z 8 Alaska 011 & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ;"~ ~-::'" .~??' - ~-'~ Di stri ct Manager DATE 12/13/84 NOTE--Report On this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Fnrm lf'l-~fl/I Submit in duplicate 11/01/84 through it/28/84 11/28/84 through 11/30/84 ATTACHMENT Suspended Operations. Fracture stimulated well with 13,500 gallons YF4 "PSD" treating fluid, 14,000 pounds 20-40 interprop, aha 4,t50 gallons flush into perfor- ations. 10,932 - 10,gSS'; 10,954 - 10,960'; 10,974 - 10,980'. RECEIVED' D£C 1 81,8~ Alaska 011 & Gas Cons, Commission Anchorage [ t! ~ O0 /3 7 ' ~- STATE OF ALASKA " ' ," ,, ALASKa..)IL AND GAS CONSERVATION Cu~..VllSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~ Workover operation [] Middle Ground Shoal 17595 Well No. 27 i2. Name of operator 7. Permit No. Amoco Production Company 83-1166 3. Address 8. APl Number P. O. Box 100779, Anchorage, Alaska 99510 50- 733-20368 9. Unit or Lease Name MGS State 17595 4. Location of Well atsurface Leg 2. Slot 5 Middle 6round Shoal Platf0rm Baker 1.985' FNL 584' FWL. Section 31. T9N R12W S.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 79.4' KB, MSI. I Ar)L 17595 10. Well No. 27 11. Field and Pool Lower Kenai Conglomerate Middle Ground Shoal Field For the Month of October ,1984 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date - 09/19/83 Depth at end of month - 11,600' MD 13. Casing or liner ru.n and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None 1 6. DST data, perforating data, shows of H2S, miscellaneous data Please See Attachment 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. /::/ ~?:~ District Manager SIGNED (..ICI ?/-.~ ~/~>~~ TITLE DATE 11/15/84 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. .......... .~ Submit in duplicate 10/01/84 through 10/02/84 10/03/84 through 10/06/84 10/07/84 through 10/12/84 10/13/84 through 10/16/84 10/17/84 through 10/18/84 10/19/84 10/20/84 10/21/84 10/22/84 10/23/84 10/24/84 through 10/30/84 ATTACHMENT Open for fl ow. Pull production equipment and RIH w/open ended tubing. Well shut-in. Run pre-frac step rate test on well. Cement squeeze perforations 10,758' - 11,115'. Drill cement 10,722' - 11,070' Perforate 10,932' - 10,938'; 10,954' - 10,960'; 10,974' - 10,980'. Run temperature survey 10,100' - 11,070' Run data frac on well. Run temperature survey 10,100' - 11,070' Back fl ow well. Pull frac tubing. R1H w/open ended tubing. Suspended operations. W. G. Smith District Manager October 16, 1984 File: DJP-528-WF Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' Monthly Report of Operations Middle Ground Shoal State 17595 Well No. 27 and Well No. 15RD Platform Baker, Cook Inlet, Alaska Attached in duplicate are the State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced wells, reporting September 1984 activities. Very truly yours, z-~J ~,~ ~: ~-~-'-'-'~- _,-'"'~ = - W. G. Smith District Manager Attachment CTJ/dds RECEIVED OCT 1 9 lOB4 Alaska Oil & Gas Cons Anch0raUa ; <-'" STATE OF ALASKA ALAS)' .- AND GAS CONSERVATION ,_ ,vllSSION 'MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~' Workover operation [] Middle Ground Shoal 17595 Well No. 27 2. Name of operator 7. Permit No. Amoco Production Company 83-116~ 3. Address 8. APl Number P. O. Box 100779, Anchorage, Alaska 99510 5o- 733-20368 4. Location of Well atsurface Leg 2, Slot 5 Middle Ground Shoal Platform Baker 1,985' FNL 584' FWL, Section 31, T9N R12W S.M. Eleva ' i fee 'di K etc.) 6. Le~LDe~l~(~J~ and Serial No. 9. Unit or Lease Name MGS State 17595 10. Well No. 27 11. Field and Pool Lower Kenai C0ngl0merate Middle Ground Sh0al Field For the Month of September .12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date - 09/19/83 Depth at end of month - 11,600' MD Open for fl ow. 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None RECEIVED .1 6. DST data, perforating data, shows of H2S, miscellaneous data None OCT 1 9 ]gll4 Alaska 0il & Gas Cons. Commission Anchom[je 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· SIGNED ~,/E'/ ..- ;: ,~ .- TITLE. DATE 10/16/84 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 September 14, 1984 File: DJP-423-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive -Anchorage, Alaska 99501 Gentlemen' Monthly Report of Operations Middle Ground Shoal State 17595 Well No. 27 Platform Baker, Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced well, reporting August 1984 activities. Very truly yours, W. G. Smith District Manager Attachment CTJ/dds RECeiVED 1 ? 1984 Gas Cons. Commission ~.nchora,ge " ~-', STATE OF ALASKA ALASK~~'' ,-:AND GAS CONSERVATION C 31SSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wellJ~ Middle Ground Shoal 17595 Well No. 27 Workover operation [] 2. Name of operator Amoco Producti0n Company 3. Address P. O. Box 100779, Anchorage, Alaska 99510 4. Location of Well atsurface Leg 2, Slot 5 Middle Ground Shoal Platform Baker 1,985' FNL 584' FWL, Section 31, T9N R12W S.M. · ica B I 6. 5. Elevati~:~n. 4ect (~1, ~S~' DF, etc.)I Lea~D~si~r~g~and Serial No. 7. Permit No. 83-116~ 8. APl Number 50- 733-20368 9. Unit or Lease Name MGS State 17595 10. Well No. 27 11. Field and Pool Lower Kenai Congl0merate Middle Ground Shoal Field For the Month of August ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date - 09/19/83 Depth at end of month - 11,600' MD Open for fl ow and pumping intermittently during the month. 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None .1 6. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED SEP 1 7 191]~, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· SIGNED LE At;;S~a O~l ~' Gas Cons. Commission Anchorage 09/14/84 DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 August 30, 1984 File: DJP-380-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' Monthly Report of Operations Middle Ground Shoal State 17595 Well No. 27 Platform Baker Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced wells, reporting July 1984, activities. Very truly yours, W. G. Smith District Manager Attachment CTJ/dds Alaska Oil & GaS Cons. Cemm[ss~on , , .- . ._ ,~-~-. STATE OF ALASKA ~ ALASK; ..L AND GAS CONSERVATION C .MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation [] Middle Ground Shoal 17595 Well No. 27 2. Name of operator AmOco ProdUction ComPan.y " 3. Address P.O. Box 100779, Anchorage, Alaska 99510 4. Location of Well at surface Leg 2, Slot 5 Middle Ground Shoal Platform Baker 1, 985' FNL, 584' FWL, Section 31, T9N, R12W, S'M. 5. Elevation in feet (indicate KB, DF, etc'.) . 79.4' KB, MSL 6. Lease Designation and Serial No. ADL 17595 7. Permit No. 83-1161~ 8. APl Number 50- 733-20368 9. Unit or Lease Name MGS State 17595 10. Well No. 27 11. Field and Pool Lower Kenai Conglomerate Middle Ground Shoal Field . For the Month of July ,19 84 q2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date - 09/19/83 Depth at end of month - 11,600' MD Open for flow 7-1-84 to 7-13-84 Pumping 7-14-84 to 7-23-84 Remove Kobe Pump 7-23-84 Open for Flow 7-24-84 to 7-31-84 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None I 6. DST data, perforating data, shows of H2S, miscellaneous data None · - ':,;.~ Goes. CcmmJssi0 /~,nchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· SIGNED '(~' ~'/~ TITLE District Manager DATE 8/30/84 - . . . t~, . NOTE--Report on th~s form ~s required ~or eac~c~endar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th-~f the succeeding month, unless otherwise directed· Form 10~04 Submit in duplicate W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 July 13, 1984 File' DJP-234-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' Monthly Report of Operations Middle Ground Shoal State 17595 Well No. 27 Platform Baker Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced wells, reporting June 1984, activities. Very truly yours, W. G. Smith District Manager Attachment CTJ/dds RECEIVED J U L 1 6 1984 Alaska 0il & Gas Cons. Commission Anchorage ' "-" STATE OF ALASKA " ALASKA £ ."AND GAS CONSERVATION CO, ]ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation [] Middle Ground Shoal 17595 Well No. 27 7. Permit No. 2. Name of operator Amoco P'roduction Company 83-116)~ 8. APl Number 3. Address P.O. Box 100779, Anchorage, Alaska 99510 4. Location of Well atsurface Leg 2, Slot 5 Middle Ground Shoal Platform Baker 1, 985' FNL, 584' FWL, Section 31, TgN, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 79.4' KB, MSL ADL 17595 5o- 733-20368 9. Unit or Lease Name HGS State 17595 10. Well No. 27 11. Field and Pool Lower Kenai Conglomerate Middle Ground Shoal Field For the Month of. June ,19 84 :12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks DSpUd. date - 09/_19/83 epth at end of month - 11,600' MD Open for fl ow 13. Casing or liner run and quantities of cement, results of pressure tests Noiie-- ~. 14. Coring resume and brief description None 15. Logs run and depth where run None ,16. DST data, perforating data, shows of H2S, miscellaneous data None J U l.,. 1 6 !984 · ~;'si-.-.a 0il & Gas Cons. C0mmissi0~ ,'Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,GNED ~)'~' ~ //~- T,TLE District Manager DATE07/13/84 NOTE--Report on this form is req~ calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 Submit in duplicate Amoco Production Company June 15, 1984 File: DJP-137-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Monthly Report of Operations Middle Ground Shoal State 17595 Well No. 27 Platform Baker Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced wells, reporting May 1984, activities. Very truly yours, W. G. Smith District Manager Attachment CTJ/dds RECEIVED JUN 1 1984 Alaska Oil & ~s Cons. Commissio~ A~'.h~age .L. ; ~- STATE OFALASKA ALASKA ~. ' AND GAS CONSERVATION CC .VIISSION MONTHLY REI ORT OF DRILLINO AND WORKOVI=R · Drilling well [] Middle Ground Shoal 17595 Nell No. 27 Workover operation [] 2. Name of operator Amoco Production Company 3. Address P. O. Box 100779, Anchorage, Alaska 99510 4. Location of Well atsurface Leg 2, Slot 5 Middle Ground Shoal Platform Baker 1, 985' FNL, 584' FWL, Section 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 79.4' KB, MSL 6. Lease Designation and Serial No. ADL 17595 7. Permit No. 83-116 8. APl Numb~er~ 50- 733-20368 9. Unit or Lease Name MGS State 17595 10. Well No. 27 11. Field and Pool Lower Kenai Conglomerate Middle Ground Shoal Field For the Month of May ,19 84 ~12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date - 09/19/83 Depth at end of month - 11,600' MD See Attachment 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None ~1 6. DST data, perforating data, shows of H2S, miscellaneous data RECEIVED None JUN 1 6 1984 Alaska Oil & Gas Oons. Gommission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,GNED~/~~~'~ TITLE District Manager DATE 06/15/84 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate ATTACHMENT 05-01-84 to O5-O8,84 Pumping 05-09-84 to 05-22-84 Shut-in for pressure build-up. 05-23-84 to 05-31-84 Open for flow, well returned to production. RECEIVED JUN 1 8 Alaska Oil & Gas Cons. Commission Anchorage W. G. Smith District Manager May 14, 1984 File' DJP-O35-WF Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Monthly Report of Operations Middle Ground Shoal State 17595 Well No. 27 Platform Baker, Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced well, reporting April 1984 activities. Very truly yours, W. G. Smith District Manager Attachment PLE'dds RECEIVED MAY 1 7 19 4 Alaska Oil & G~s Cons. Commission Anchorage ' ' /--' STATE OF ALASKA ~---,. /~)/D / .... ,-- '~ ' ~ 'ALASKA £ ~AND GAS CONSERVATION CO, IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS// , · Drilling well [] Workover operation [] Middle Ground Shoal 17595 Well No. 27 2. Name of operator 7. Permit No. Amoco Production Company. 83-116j~ 3. Address 8. APl Number P. O. Box 100779, Anchorage, Alaska 99510 5o- 733-20368 9. Unit or Lease Name MGS State 17595 4. Location of Well at surface Leg 2, Slot 5 Middle Ground Shoal Platform Baker~1,985' FNL~584' FWL, Section 31, T9N~ R12Wj S.M. 5. Elevati~)in_f~et_(iadicate_l~B DF, etc.) I 6. · 4 KB, MSL' Le~)~}es~l~ and Serial No. 10. Well No. 27 11. Field and Pool Lower Kenai Conglomerate Middle Ground Shoal Field For the Month of Apri 1 , 19__ 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date - 09/19/83 Depth at end. of month - 11,600' MD See Attachment 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None KELEIVEU MAY i 7 i9 J4 Alaska 0ii & G~-s Cons. Commission Anchorage ,16. DST data, perforating data, shows of H2S, miscellaneous data 04-24-84 Reperforated the following intervals with 4-inch tubing-conveyed perforating guns with approximately 2,000 psi underbalanced condition, 4JSPF, and 90 degrees phasing' 10,758' to 11,058' and 11,087' - 11,115'. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· //~......~.~ .~~.~~ District Manager SIGNED , - TITLE DATE 05/15/84 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate ATTACHMENT 04-01-84 to 04-14-84 Pumping 04-14-84 to 04-19-84 Shut-in for pressure build-up in preparation for reperforating. 04-20-84 to 04-24-84 Pulled tubing and bottomhole assembly. Ran tubing-conveyed perforating guns, bottomhole assembly, and tubing and reperforated with approximately 2,000 psi underbalanced condition. 04-25-84 to 04-30-84 Well returned to production. Alaska Oil & Gas Cons. Corn, mission Anchorage L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 9[}510 907-272-8471 April 13, 1984 File' WGS-O77-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Co~mdssion 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' Monthly Report of Operations Middle Ground Shoal State 17595 Well Nos. 23 and 27, Platform Baker Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced wells, reporting March 1984, activities. Very truly yours, W. G. Smith District Manager Attachment PLE' dmh /~-" STA~:E OF ALASKA ALASK ~L'AND GAS CONSERVATION ~ .... ,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well · MJddle Ground Shoal ]7595 Well No. 27 2. Name of operator Amoco ProductJon Company 3. Address P. O. Box 100779,-Anchorage, Alaska 99510 4. Location of Well at surface Leg 2, Slot 5, Middle Ground Shoal Platform Baker, 1,985' FNL, 584' FWL, Sec. 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 79.4' KB, MSL ADL 17595 Workover operation [] 7. Permit No.# 83-116~ 8. APl Number 50- 733-20368 9. Unit or Lease Name MGS State 17595 10. Well No. 27 11. Field and Pool Lower Kenai C0ngl0merate Middle Ground Shoal Field For the Month of March ,1984 ,12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 03-27-84 to 03-30-84 - Bled off well and DSpUd. date - 09/19/83. epth at end of month - 11,600' MD 03-01-84 to 03-26-84 - Shut-in for fluid level buildup 13. Casing or liner run and quantities of cement, results of pressure tests performed mud acid stimulation treat- ment usinQ 1,000 gallons 10% HCL pre- flush, 2.000 gallons 6% HCL - 1-½% HF, and 1,000 gallons IO%.HCL ~fter- flush. Job performed with coiled tubing, u¢it 03-31-84 - we/ ~eturned to production . None 14. Coring resume and brief description None 15. Logs run and depth where run None ,16. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED APr( 1 6 1984 Anchnr~qe 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. District Manager 4/13/84 SIGNED TITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 March 15, 1984 File- WEN-O75-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' Monthly Report of Operations Middle Ground Shoal State 17595 Well Nos. 23 and 27, Platform Baker Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced wells, reporting February 1984 activities. Very truly yours, W. E. Nielsen Supervi sor-i n-Charge Attachment PLE:seh ,~'"'" - ' STATE (JFALASKA _--- ALASKJ ,L AND GAS CONSERVATION £ ,MISSION MONTHLY REPORT OF' DRILLING AND WORKOVER OPERATION , 1. Drilling well)~ Hi ddle Ground Shoal 17595 Nell No. 27 Producti on Company 2. Name of operator Amoco 3. Address P. O. Box 100779, Anchorage, Alaska 99510 , Slot 5, Middle Ground Shoal Pla'tform , 1,985' FNL, 584' FWL, Sec. 31, T9N, S.M. 4. Location of Well at surface Leg 2 Baker R12W, Elevation in feet 79. (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 4' KB= MSI.I ADL ]7595 Workover operation [] 8. APl Number 5o- 733-20368 9. Unit or Lease Name MGS State 17595 10. Well No. 27 11. Field and Pool Lower Kenai Conglomerate Middle Ground Shoal Field FOr the Month of February ,1984 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date - 09/19/83 Depth at end of month - 11,600' MD 02-01-84 - Shut-in for fluid level buildup to 02-29-84 _' 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None i 6. DST data, perforating data, shows o{ H2S, miscellaneous data None MAR ]. 5 1984 Alaska 0il & Gas O0ns. Commission Anci~rage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUpervisor- i n-Charge 3/15/84 Oil and Gas Conservation Commission by the 15th of the succeed'lng month, unless otherwise directed. ~ 'Submit in duplicate Form 10-404 _ i L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 January 15, 1984 File' WEN-172-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, A1 aska 99501 Gentlemen' Monthly Report of Operations Middle Ground Shoal State 17595 Well Nos. 23 and 27, Platform Baker Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced wells, reporting January 1984 activities. Very truly yours, W. E. Nielsen Supervi sor-i n-Charge Attachment PLE'seh - ~-~' STATE Or: ALASKA ~-- ~ -' ' '- : ALASKA'" .LAND GAS CONSERVATION C~ ,MISSION MONTHLY REPORT OF DRILLINO AND WORKOVER OPERATIONS ,,f'-'" J/F?I _.~ 1. Drilling well I~ Middle Ground Shoal 17595 Nell No. 27 :2. Name of operator Amoco Production Company 3. Address P. O. Box 100779, Anchorage, Alaska 99510 4. Location of Well at surface Leg 2, Slot 5, Middle Ground Shoal Platform Baker, 1,985' FNL, 584' FWL, Sec. 31, TDN, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 79.4' KB 6. Lease Designation and Serial No. ADL 17595 Workover operation [] 9. Unit or Lease Name MGS State 17595 8. APl Number 50- 733-20368 For the Month of January 10. Well No. 27 11. Field and Pool Lower Kenai Conglomerate Middle Ground Shoal Fiel ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date - 09/19/83 Depth at end of month - 11,600' MD See attachment 13. Casing or liner run and quantities of cement, results of pressure tests 01-03-84 7" liner run from 8,590' MD to 11,592' MD. Cemented with 925 sacks of class 'G' cement. Tested liner lap to 3,500 psi for 10 minutes - ok. 14. Coring resume and brief description · ~ ,~ ,,., . ~ f~,,', ,, .. f_,.. ..... 15. Logs run and depth where run ': ..... 01-9-84 Ran cased hoqe gamma ra~v/casing coqqar ]ocator from 4,000' to 11,511' .1 6. DST data, perforating data, shows of H2S, miscellaneous data 01-14-84 to 01-15-84 perforated 10,760' - 10,874' , 10,900' - 11,058' , and 11,088' - 11.,114' in dieseq using Schqumberger 2-1/8 inch Enerjet thr0ugh-tubin perforating guns at 4JSPF and 0 degree phasing. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ill' ~'. NJ ~, ~. /~,~1/7 Superv~sor-~n-Charge 02/15/84 SIGNED__V~' ' I" 'l '~',,~-¢.,~V~ ]',./!.,J~ ~A,~ . TITLE ....... DATE NOTE--Report on this form is require~J for ~c~ calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the l,F~th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate 01-01-84 to 01-03-84 01-03-84 to 01-05-84 01-05-84 to 01-06-84 01-06-84 01-06-84 to 01-07-84 01-08-84 01-09-84 to 01-10-84 01-11-84 01-11-84 to 01-13-84 01-14-84 to 01-16-84 01-16-84 to 01-20-84 01-20-84 to 01-23-84 01-24-84 to 01-31-84 01-31-84 ATTACHMENT Drilled from 11,464' to 11,600' Ran and cemented 7" liner Drilled out cement from 5,569' to 8,590' Ran 9-5/8" casing scraper to 8,590' Pressure test liner lap - ok Ran 7" casing scraper to 11,511' Ran cased hole gamma ray/casing collar l ocator from 4,000' to 11,511' and gyroscopic survey from surface to 11,511'. Displaced well with diesel Ran Kobe hydraulic pumping system Perforated well and ran pressure gradient survey Produced well Shut-in for fluid level buildup Produced well Shut-in for fluid level buildup L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 January 13, 1984 File' WEN-O68-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' Monthly Report of Operations Middle Ground Shoal State 17595 Well No. 27, Platform Baker Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced well, reporting December 1983 activities. Very truly yours, W. E. Nielsen Supervi sor-i n-Charge Attachment PLE-seh RECEIVED Alaska 0il A Gas Cons. (,oi~lmlssjor Anchoracte " ,~---.. STATE Or: ALASKA ALASKA, . AND GAS CONSERVATION CC~-'~llSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ,. 1'~ Drilling well I--I~ ........... Workove~ ~-~ Middle Ground Shoal 17595 Well No. 2'7 2. Name of operator Amoco Production Company 3. Address P. O. Box 100779, Anchorage, Alaska 99510 4. Location of Well · at surface Leg 2, Slot 5 Middle Ground Shoal Platform Baker 1985' FNL 584' FWL, Section 31, T9N R12 W S.M 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 79,4' KR A~I 17.~g.~ 7. Permit No. _/ 83-116~ 8. APl Number 50- 733-20368 9. Unit or Lease Name M~ dd I e Gr0u Shoal State 17595 10. Well No. 27 11. Field and Pool Lower Kenai Conglomerate Middle Ground Shoal Fie For the Month of December ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date - 09/19/83 Depth at end of month - 11,464' MD See Attachment 13. Casing or liner run and quantities of cement, results of pressure tests 12-02-83 9-5/8" casing run from 0' - 8844' MD. Cemented with 1400 sacks of class "G" cement. Tested to 1500 psi for 30 minutes. 14. Coring resume and brief description None 15. Logs run and depth where run 12-19-83 to 12-20-83 Ran gamma ray 6500' Ran dual induction and diplog 8844' - 10,407' - 10,407' 12-29-83 Ran dual induction density-neutron, diplog, gamma ray 8844' - 11,338'. 6. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED : '"'~ !'"t :' "' ' Alaska 0il & Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Supervi sor-i n-Charge SIGN TITLE DATE Arml!qraile 01/13/84 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate ATTACHMENT 12-01-83 to 12-04-83 12-04-83 12-05-83 to 12-06-83 12 -06 -83 to 12-07-83 12-07-83 12-09-83 12-10-83 12-11-83 to 12-12-83 12-12-83 to 12-19-83 12-19-83 to 12-20-83 12 -20-83 to 12-29-83 12 -29 -83 12 -30-83 Conditioned hole. Ran and cemented 9-5/8" casing to 8844' MD. Drilled out float shoe to 8860' MD. Ran leak off test to 13.2 ppg equivalent mud weight. Clean out to fish at 8959'. Set cement plug from 8959 - 8846' and polished off at 8863' [second side track depth]. Dyna-drill 8863 - 8935' Drilled 8935 - 9179' Dyna-drill correction run 9179 - 9239'. Drilled 9239 - 9417' Dyna-drill correction run 9417 - 9451'. Drilled 9451 - 10,407' Logging Drilled 10,407 - 11,367' Logging Drilled 11,367 - 11,464' RECEIVED ' ~A ~.! '~ r.. ir Alaska Oil & G~s co~s. <,~, ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Rece:iPt of the following material which was transmitted via, .... . :'-' × is hereby acknowledged ' QUANTITY DESCRIPTION · RECEIVED: DATED: Copy sent t~sender YES // NO ,.. L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 December 15, 1983 File' LAD-1191-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' Monthly Report of Operations Middle Ground Shoal State 17595 Well No. 27, Platform Baker Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced well, reporting November 1983 activities. Very truly yours, L. A. Darsow Di stri ct Superintendent Attachment PLE:cm ~-'. STATE OF ALASKA ~_~ /~¢ /'~ ..... ~ · ALASKAC "AND GAS CONSERVATION CC '~ISSION b/~k.<',~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well )~ Workover operation [] Middle Ground Shoal 17595 Well No 27 2. Name of operator ° 7 Permit No Amoco Production Company ' 83-1~6~ 3. Address P. O. Box 100779, Anchorage, Alaska 99510 8. APl Number 4. Location of Well at surface Leg 2, Slot 5 Middle Ground Shoal Platform Baker 1985' FNL 584' FWL, Section 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 79,4' KB I6'ADLLease ~)~g~tion and Serial No. For the Month of November ,19 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date - 09/19/83 Depth at end of month - 8973' MD (Side track #1) See Attachment 13. Casing or liner run and quantities of cement, results of pressure tests , None 14. Coring resume and brief description None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED~'~',~-_ _ ~"~~_~-- ~'~--~',~'~ -- ~.. o TITLE District Superintendent 5o- 733-20368 9. Unit or Lease Name Middle Ground Shoal State 10. Well No. 27 11. Field and Pool Lower Kenai Congl0merate Middle Ground Shoal Field 83 DATE 12/15/83 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Attachment 11-01-83 11-02 - 11-09-83 11-10 - 11-11-83 11-12 - 11-14-83 11-14 - 11-23-83 11-24-83 11-25 - 11-30-83 Drilled to 8964'. During reaming 7838 - 7901', rotary table failed. Started to trip out of hole. Bit stuck at 7830'. Jar and work stuck pipe. Back off at 7498' [332' fish in hole]. Set cement plug from 7498 - 7277' and polished off at 7303' [Side track depth]. Dyna-drill 7303 - 7383'. Drilled from 7383 - 8973'. On trip out, lost bit and stabilizer [7' fish in hole]. Attempt to fish and pushed to bottom. Top of fish at 8959'. Conditioning hole to run 9-5/8" casing. L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 November 10, 1983 File' LAD-1082-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Monthly Report of Operations Middle Ground Shoal State 17595 Cook Inlet, Alaska Commission Well No. 27, Platform Baker Attached in duplicate is State of Drilling and Workover Operations, reporting October 1983 activities. Very truly yours, L. A. Darsow District Superintendent Attachment Alaska Form 10-404, Monthly Report of for the above referenced well, PLE/seh !. Alaska Oil ~.'~ Gas cou,s_ :, ',"~noholu_go ~-'°ru~niS:~iOn .-, '-' .... STATE OFALASKA ALASKA~'- 'i:AND GAS CONSERVATION C( '~AISSION MONTHLY REPORT oF DRILLING AND WORKOVER OPERATIO 1. Drilling well {~ Workover operation [] "~ Middle Ground Shoal 17595 Well No. 27 2. Name of operator 7. Permit No. ' Amoco Production Company 83-Ai'6~6- /~ ~7 3. Address P. 0. Box 100779, Anchorage, Alaska 99510 4. Location of Well atsurface Leg 2, Slot 5 Middle Ground Shoal Platform Baker 1985' FNL 584' FWL, Section 31, T9N R12 W S.M 5. Elevation in feet (indicate KB, DF, etc.) 79.4' KB I6. Lease Designation and Serial No. ADL 17595 8. APl Number 50- 733-20368 9. UnitorLeaseName Middle Groun( Shoal State 17595 10. Well No. 27 11. Field and Pool Lower Kenai Conglomerate Middle Ground Shoal Fiel For the Month of October ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date - 09/19/83 Depth at end of month - 8956' MD Footage drilled - 5536' No fishing jobs Made Dyna-drill correction runs from 6875' - 6955' and 7095' - 7161' 13. Casing or liner run and quantities of cement, results of pressur9 tests None 14. Coring resume and brief description None 15. Logs run and depth where run None .16. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~ . , TITLE DATE 11/10/83 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas' Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 October 26, 1983 File' LAD-1034-WF C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subsequent Report MGS 17595 Well No. 27 - Change of Casing Plans Platform Baker, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-403, Sundry Notices and Reports on wells describing our change of casing plans on the subject well. The 20-inch casing was omitted, due to a restriction at 289-feet, which was believed to be the base.,Of, the 30-inch conductor. The 17-1/2 inch hole was continued and .the-.?ii.:3'~3/8 inch casing was set at 3,407 MD. If you have any additional questions, please contact Kevin Smith at 272-8471. Very truly yours, L. A. Darsow District Superintendent Attachments KLS/seh Alaska 0!io. ° ,.~as Cons. ,a,.n. shorag0 STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL E~ COMPLETED WELL [] 2. Name of Operator 7. Permit No. Amoco Production Company 83-116 3. Address 8. APl Number P. O. Box 100779, Anchorage Alaska 99510 5o- 733-20368 OTHER [] 4. Location of Well Leg 2, Slot 5, MGS Platform Baker 1985' FNL, 584' FWL, Section 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 79.4' KB 6. Lease Designation and Serial No. ADL 17595 12. 9. Unit or Lease Name i ddle Ground Shoal State 17~ 10. Well Number 27 11. Field and Pool Middle Ground Shoal Field Lower Kenai Conglomerate Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 95 NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The 20-inch casing string was omitted due to a restriction encountered at 289' KB on 9-20-83. The 17-1/2 inch hole was continued to 3,420' MD, at which time the 13-3/8 inch casing was set at 3,407' MD on 9-28-83. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Distri ct Super1 ntendent Signed ,-~-~ - ~,,,~._~'~ Title The space below for Commission us~ Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 October 14, 1983 File' LAD-iOO4-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Commi s s i on Gentlemen: Monthly Report of Operations Middle Ground Shoal State 17595 Cook Inlet, Alaska Well No. 27, PlatfOrm Baker Attached in duplicate is State of Alaska Drilling and Workover Operations, for the reporting September 1983 activities. Form 10-404, Monthly Report of above referenced well, Very truly yours, L. A. Da rs ow District Superintendent Attachment PLE/seh STATE OF ALASKA ALASKA' _AND GAS CONSERVATION C( ".MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Middle Ground Shoal 17595 Well No. 27 7. Permit No. 2. Name of operator //.,,~ Amoco Production Company 3. Address 8. APl Number P. 0. Box 100779, Anchorage, Alaska 99510 50_733-20368 9. Unit or Lease Name Mi ddi e Ground Shoal State 17595 4. Location of Well at surface Leg 2, Slot 5 Middle Ground Shoal Platform Baker 1985' FNL 584' FWL, Section 31, T9N R12 W S.M 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 79.4' KB ADL 17595 10. Well No. 27 11. Field and Pool Lower Kenai Conglomerate Middle Ground Shoal Field For the Month of September ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date - 09/19/83 Depth at end of month - 3420' MD Footage drilled - 3420' No fishing jobs Unable to set 20" casing due to a restriction at bottom of 30" conductor set at 289'. 13. Casing or liner run and quantities of cement, results of pressure tests 09-28-83' Ran 3407' of 13-3/8" casing. Cemented with 2500 sacks Class "G" cement. Cement top 290'. Did cement "top job" with 570 sacks Class "G", cement to surface. 14. Coring resume and brief description None 15. Logs run and depth where run None 1 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. '~ · District Superintendent SIGNED TITLE 10/14/83 DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. .Form 10-404 Submit in duplicate MEMORANDUM State of Alaska TO: C~ on D^TF: October 4, 1983 THRU: Lonnie C. Smith Commissioner TELEPHONE NO: FROM: Harold R. Hawkins -,.,~z' ~ SUBJECT: Petroleum Inspeetor~ .~ Witness BOPE Test Amoco MGS Well Eo. 27, Sec. 31, T9[~, RI2W, SM, Permit No. 83-116. .F.riday, September 30,_ ~983: I left ~chorage at 6:00 am bp AA1 to Kenai, arriving on the Baker Platform at 8:45 am. I witnessed the BOPE test, there 'were no failures. I filled out an A.O.G.C.C. report which is attached. In summary, I witnessed the BOPE test that Parker Drilling performed for Amoco on MGS Well No. 27. The BOPE tests were satisfactory. Attachment '0~-001A(Rev. 10/79) '~G #4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Date Well Operator /~ /~ /) Well Md Z?,f Location: Sec Drilling Contractor Representative Permit # . ? :-- ~. Casing Set Rig ~ /6~ Representativ~ Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure ~~ psig Pressure After Closure /~--/~ psig 200 psig Above Precharge Attained: ~' min,~ sec. Full charge Pressure Attained: . q min~ sec Controls: Master Remote :%/~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly. Lower Kelly Bal 1 Type Inside BOP Choke Manifold No. Valves ~: No. flanges /6 Adjustable Chokes Hydrauically operated choke Test Pressure / Test Pressure Test Pressure Test Pres sure Test Pressure Test Results: Failures Repair or Replacement of failed equipment to be made within Test Time ~ hrs ~~ days and Inspector/Commission office notified. Remarks: Distribution orig. - A0&GCC cc - Operator cc - Supervisor Inspector / L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 September 22, 1983 File' LAD-933-WF C. V. Chatterton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir' Change of Casing Plans MGS 17595 Well No. 27 Platform Baker, Cook Inlet, Alaska Attached in triplicate is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells describing our change of casing plans on the subject well. In telephone conversations between J. K. Trimble, with the AOGCC, and K. E. O'Connell, with Amoco, on September 21, 1983 verbal approval was given for omitting the 20-inch casing on MGS 17595 Well No. 27. We found it necessary to alter our casing plans when a 26-inch hole opener would not pass through a restriction at 289-feet. The 17-1/2-inch hole has already been drilled to 613-feet and we were proceeding to open that hole to 26-inch and then run the 20-inch casing. This restriction could be the base of the 30-inch conductor, which was pile driven, or possibly the 20-inch casing of a close offset well. Rather than spend time on a potentially unsuccessful milling operation, we plan to continue drilling the 17-1/2-inch hole, kick-off and build angle, and drill to 3000 - 3500' MD, and run 13-3/8-inch casing. This casing will be cemented to surface as originally planned. Prior to drilling ahead from 613-feet, a 30-inch to 20-inch crossover will be installed on the 30-inch conductor at the surface. This will allow installation of the 20-inch annular blow out preventer and diverter system. C. V. Chatterton LAD-933-WF September 22, 1983 Page 2 Thank you for your prompt approval. If you have any additional questions, please call Kevin O'Connell at 272-8471. Very truly yours, L. A. Darsow Di stri ct Superintendent Attachments KEO: cm .~'-"- STATE OF ALASKA ALASK~ ~.~L AND GAS CONSERVATION b~.,dMISSlON SUNDRY HOTICES AND REPORTS ON WELLS 1. DRILLING WELL~ COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. Amoco Production Company 83-116 3. Address 8. APl Number P. 0. Box 100779, Anchoraqe, Alaska 99510 so-733-20368 4. Location of Well Leg 2, Slot 5, MGS Platform Baker, 1985' FNL, 584' FWL, Section.31, T9N, R12W, S.M. 6. Lease Designation and Serial No. ADL 17595 5. Elevation in feet (indicate KB, DF, etc.) _ 79.4' KR 12. 9. Unit or Lease Name Middle Ground Shoal .qtate 17595 1 O. Well Number i 27 11. Field and Pool Middle Ground Shoal Fi eld: Lower Kenai Conglomerate ! Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [~ Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans ,r~ Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company plans to eliminate the 20-inch casing string, originally planned to be set and cemented at 600' KB. This is due to a restriction encountered at 289' KB on 9-20-83 which will not allow a 26-inch hole opener to pass through, but will allow a 17-1/2-inch bit to pass through. As of 9-21-83, we have 17-1/2-inch hole drilled to 613-feet. Rather than mill on the "tight spot" at 289-feet (which could possibly be an offset well, MGS #13, or the base of the 30-inch conductor slot) we plan to continue drilling 17-1/2-inch hole to 3500' MD and run and cement 13-3/8-inch casing. NOTE: Prior to drilling ahead from 613-feet, a 20-inch annular blow out preventer and diverter system will be installed. The space below for Commission use Dale Conditions of Approval, if any' Approved by B~ LO~,,~E C. S~ITlt Approved Copy Returned., .... By Order of COMMISSIONER theComm~ss~on Dalt: Form 10-403 Rev. 7-1-80 Suhml! "lntenl~ons" ~rl Trll)licate and "StJbSe(iuenf kle;~o~ls" ~n r~)tJi)llcale July 26, 1983 Mr. L. A. Darsow DistriCt Superintendent Amoco Production Company P. O. Box 100779 Anchorage, Alaska 99510 Re= Middle Ground S~.~oal 'State 17595 No. 27 Amoco Production .Company Pe~it No. 83-116 Sur. ?_~c. I985'~%-tL, 584'FWL, Sec. 31, T9N, R12W, SM. Btmhole Loc. 973'F~IL, 1925'FWL, Sec. 30, T9N, R12W, SM. Dear Mr. Darsow.. Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a ~ud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systen~s have been cla~sified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, ~-~apter 3, Article 7 and the regulations pror~uI~ated thereunder (Title 18, Alaska Administrative Code, Chapter ~O) and by the Federal Water Pollution Control Act, as amended. Prior to co~mencing operations you may be comtacted by a representative of the Depar~ent of Envirop~nentat Conservation. To aid us in scheduling field .work, please notify this office 24 hours prior to commencing installation of the blowout Mr. L. A. Darsow -2- Middle Ground Shoal State 17595 Mo. 27 July 26, 1983 prevention equipment s° that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing' before drilling below the shoe of the conductor pipe. In the eVent of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Alaska Oil and Gas Conservation CommissiOn be: 6,H/A Enclosure cc~ Departm~-nt of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. la. Type of work. 2. Name of operator STATE OF ALASKA ,--', ALASKA~., AND GAS CONSERVATION CC ,~IlSSION PERMIT TO DRILL 20 AAC 25.005 lb. Type of well SERVICE DRILL [] REDRILL [] DEEPEN [] EXPLORATORY [] DEVELOPMENT OIL ~[] DEVELOPMENT GAS [] SINGLE ZONE [] MULTIPLE ZONE [] ,:;.._ - I;. Amoco Production Company 3. Address P.O. Box 100779, Anchorage, Alaska 99510 4. Locationofwellatsurface Leg 2, Slot 5, MGS Platform Baker 1985' FNL, 584' FWL, Section 31, TDN, R12W, S.M. Attopofproposedproducinginterval G-1 sand at -7600' subsea, 1700' FNL 2000' FWL, Section 30, TDN, R12W, S.M. Attotaldepth 973' FNL, 1925'FWL, - 9531' subsea, Section 30, TDN, R12W, S.M. 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 79.4' KB ADL 17595 12. Bond information (see 20 AAC 25.025) Type Blanket surety and/or number Surety - 874698 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 20 miles NW of Kenai, AKmi~es 4680' FEL of ADL 17595 feet 16. Proposed depth (MD & TVD) 9. Unit or lease name Middle Ground Shoal State 175! 10. Well number 27 11. Field and pool Middle Ground Shoal Field Lower Kenai Conglomerate Amount $200,000 tl 5. Distance to nearest drilling or cpmpleted 18 we~ is 1250' S30W(G-1 18. Approximate spud date 08-15-83 17. Number of acres in lease 112000' ~D, 961!' TV~ feet 5105 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 750 feet. MAXIMUM HOLE ANGLE 50 Ol(see2OAAC25.035(c) (2) 21 Proposed Casing, Liner and Cementing Program 1210 4069 psig@ 0 ~ Surface W/Wi ps,g@9611 ft. ID ITVD) SIZE Hole 26" 17.5 12.25 Casing 20" Weight 94# 13.375" 72# 9.625 54,68# 40,43. 47,53. CASING AND LINER Grade COupling K-55 I Butt I S-95 I Butt K-SS I Butt #S-95 I Butt S-95 Butt Length SETTING DEPTH MD TOP TVD 600 3000 0 I 9750 MD BOTTOM TVD 600 600 3000 ~1 2690 I 9750 17500 I I QUANTITY OFCEMENT (include stage data) To surface, Class G To surface, Class G To cover 500' above Uppermost productive 8~5 7 29# 2450 9550 7320 12000 9611 To cover entire liner C1 ass G 22. Describe Proposed Program' ._ Amoco proposes to directionally drill Well No. 27 from le~_ v ~, ~ Slot 5, Middle Ground Shoal Platform Baker to a Lower Kenai Conglomerate G-1 target at -7600'SS, 1700' FNL, 2000'FWL, Section 30, TDN, R12W, S.M. Total depth is estimated to be at 12000' MD, 9611' TVD after adequate penetration of the G-5 zone. After log evaluations, zones af interest will be perforated, and the well placed on hydraulic lift. There are no affected operators. A location plat and BOP;E. sketches are attached. NOTE- Casing design ~afety factors of 1.12! and 1;8 will be used for collapse, burst and tensile strengths respectively. Estimated maximum mud weight is 11.9 ppg. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~--~'~~ ~~ TITLE District Superintendent DATE 7/15/83 The space below for Commission use Samples required I-lYES XNO Permit number APPROVEDBY / / ~ Form 10-401 Rev. 7-1-80 Mud log required []YES XNO Approval date ,~"0'D~6/8~ . CONDITIONS OF APPROVAL I Directional Survey required IAPl number ,,~ES []NO 50- '2'~5- zosKo~ SEE COVER LETTER FOR OTHER REQUIREMENTS ~OMMISSIONER DATE .T~lv 26. 1DR3 by order of the Commission Submit in triplicate ter in ole :one , 1.0 31 31 · : o. SEW/4.~C, M£.~.i~I~,N , ALASKA SCALE I" = I000' LEG ~"J'~) 3 LEG ''" L&T 8C~ 49" 45.75" LONG I$1° 29' O0 95- ¥ : 2,498,059.8 x = 235, 255.0 FRC,~! N.W COR. ['-~54' SOUTH 8~ 544' EAST LEG NO 2 LA-T. 60° 49' 45.22" LONG 151° 29' 00.07" Y = 2,498,014.46 X : 235,297. 30 FROM N.W. COR. 1989' SOUTH & 588' EAST LAT. 60° 49' 44.70" LONG 151° 29' Cl. 41" Y : 2,4c~7,9£5.55 X = 255,230-30 FROM N.W. COR. 2041 SOUTH & 522 EAST CERTIFICATE OF SURVEYOR I h~rsby licensed Alaska sgrwey that ~"*ify . c..,, that I am properly registered and to prastice land surveying in the State of and that this plat represents a location made by me or under my supervisidn and dimensions and other details are correct. £ JR,"2 / ~ /__~¢,¢, T9N T 8N LEG NO 4 LAT. 50° 49' 45.23" LONG 15;° 29' 02.29" Y= 2, ~,981018.88 X= 235, 187.78 FRO,*,{ N.W OCR. 1987 SOUTH ~ 47,3' EAST NOTE The location of platform legs was accomplished by using U.S.C.& G.S. monument's Tad~ Boulder,and Cost, BLM c~)h- trol points CET I0, and Granite Point Native Hub., and triangulation stations East Foreland Light OfFset , and Amass Dock. 32 CO0~ INLET CORRECTION LINE FIRST ORDER CONTROL POiHT "PA H" 07'..! PLA'J'FOR;'¥1 "B" ..;=ATED t'bl 3~/~,'~,'~ ;,'4, P~G/~ACT~= :Z~ 31,T9~,~ IZ'.'t,~ ' .......... %" PAN AMERICA PO 30X 779 A:~CH~-~ SUR~'EYE3 3Y E M. LI" ,,DS & ASSOC. '"' v ~"' IV! '-~T~, Amoco Production Comp~ ;AMOCO" ENGINEERING CHART I · NYDRIL / _ANNDLhR B0P/. .g~AFF~A ' EAr'1 . I L ! 3o00 I SHEET NO. OF FILE APPN 6'-I "L,.~ ) ~,~ - SHEET NO. OF ~T~ Amoco Production Comp~. f ~,~E ~,~MOCO . EN~INEERIN~ CHAET ................. ....... ~ ~- .-~-4 - ~--~--- ~ ~.-~ ..... ~ .... ~ . . ~ ~ ...... ~ .~ , ~ ~ .... ~ ...... .... /1 · ~ ' -. " . . '' ~~~ /' '~:"~x I ' " . " , g 2" ! J [ [ [[ [ 11 [ ~ i 1[1ii i I i i DLE flROUND SHO^L FIELD - PLAIF~ B^KER . SCALE' NW Quarter Section 30, T9N, R12W with total depth location of existing Wells No.-10 and 18 a nd prop, osed .e~ll No. 27 I 29 I ! : ! I I I I I I I -I I I I I- I I I I I I I I I 9 I R12W / - - "'G""-T ~T E O"~T'"U'"'R~- I SPID£R MAP W/TOP~.~NIES ! Figure 18 i IdGg 9 25 p' I inch = approximately 1665 feet · . .. SCALE' p FI I 'r~ I I~1 I I III ri r i i~ I II _,..DDLE GROUND SHOAL FIELD - PLATF.~,~M BAKER With Location-of Proposed MGS 17595 Well No. 27 2~ I 9~ N~ I I I I I. I I I I -I I 29 -9493 25 I I i ! [ I I I i -! I 9 36 ,, -~,,,,, i "* · -7337 I I G-1 STRUCTURE I Figure 18 L. I inch = approximately 1665 feet Amoco Production Comp,. ,y ENGINEERING CHART Sheet No. Of File Appn ALASKA OIL AND GAS COI~$E£VATiOH CO/?,~I$SIOfl Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501'-3192 TELEPHONE(907) 279'-1433 July 20, 1983 A D M I N I S T R A T I V E A P P R 0 V A L NO. 44.36 Re- The application of Amoco Production Company to drill complete, and produce the Middle Ground Shoal 17595 No. 27 well in the MGS "G" Oil Pool in the Middle Ground Shoal Field. Mr. L. A. Darsow District Superintendent Amoco Production Company P. O. Box 100779 Anchorage, Alaska 99510 Dear Mr. Darsow:. The referenced application was received on July 19, 1983 and stated that the drilling of the well is necessary to recover reserves from the northern portion of the field. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion, and producing of the referenced well pursuant to Rule 6 of Conservation Order No. 44. Yours very truly, Harry W. Kugzer Commi s s ioner BY THE ORDER OF THE COMMISSION be:3:E L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 July 15, 1983 File' LAD-750-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Si r- Application for Permit to Drill Middle Ground Shoal 17595 Well No. 27 Platform Baker, Cook Inlet, Alaska Attached in triplicate is a completed State of Alaska Form 10-401, Application for Permit to Drill for Middle Ground Shoal 17595 Well No. 27. We propose to directionally drill this well from Middle Ground Shoal Platform Baker, utilizing Leg 2, Slot 5, to a target location at the top of the Lower Kenai Conglomerate G-1 zone, -7600' subsea, 1700' FNL, 2000' FWL, Section 30, T9N, R12W, Seward Meridian. This well is to be completed as a producing well to recover reserves from the northern portion of the Middle Ground Shoal field. Also attached is our company draft No. 226480 dated July 15, 1983 for $100.00 to cover the filing fee. Two plats showing the location of the well in relation to the Middle Ground Shoal structure and a Platform Baker survey plat are attached, along with sketches of the BOP equipment to be used. Since this will be the third well completed in the Northwest quarter of Section 30, we also wis,,~ obtain an exception to the provisions of Conversation O~dated September 12, 1969) of the Alaska Oil .1l~~and-G'a~-~h~h-~-rvation C6-mmission. The other wells completed in this quarter section are: MGS 17595 Well No. 10 - Shut-in producer (March, 1968) MGS 17595 Well No. 18 - Water injector Mr. C. V. Chatteron File- LAD-750-WF July 15, 1983 Page 2 Drilling of the subject well is estimated to start in mid-August, 1983. Please contact K. E. O'Connell in our Anchorage office if you have any questions concerning this application. Very truly yours, L. A. Darsow District Superintendent Attachments KEO/seh CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc (2 thru 8) Lease & Well No. Company YES NO REMARKS 1, Is the permit fee attached ........................................... 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .............. 4, Is well located proper distance from other wells ............. ' ....... 5, Is sufficient undedicated acreage available in this pool ,,,,,,,,,,,, .~.~ 6, Is well to be deviated and is well bore plat included~ .......... 7, Is operator the only affected party .................... 8, Can permit be approved before ten-day wait .......................... (3) Admin ~.,, .~-219-_ff.~F (9 thru 11) ( 4 ) C a s g~_~'~.~ 7 ~.,5- P,_~ (1~ thru 20) (5) BOPE ~..~../ (21 thYu 24) (6) 9. Does operator have a bond in force .................................. ~f< 10 Is rvatio .rd needed ,~K . a conse n er .... ...... ...... .... .................. 11. Is administrative approval needed ................................... ~,. . 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is conduct tring provided ' or s ........*.................e..ee.e..e.... Is enough cement used to Circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... 1 f g f h Wil sUr ace casin protect res water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... ~ Is a diverter system required ....................................... ~. Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~~ psig ''/z~__ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. · ' ' / 'I .t . , , . .,.' ./ , / .' . ~ ! / ' ,' ., t / , ,- , ' 0 Geology: Engineering: !IWK J-J~o~_, LC S ~-~~ BEw / '.dVA z %:J ;.~ J KT ~ HJH JAL ---- MTM rev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. Ct'?~V! fFICI~-ICATIONS Company AMOCO PRODUCTION CO. MGS 17595 WELL NO. 27 Field MIDDLE GROUND SHOAL County, State KENAI, ALASKA Date 12-28-83 AP1 5073320368 (Ab'_-rev.) .C~ar. dard Cu:-ve .Name Lo~s t"sed Scale FOCUSED RFOC RESISTIVITY DIFL .2 - 2000 SP I SPONTANEOUS POTENTIAL t DIFL 45 - -105 . i DEN I DENSITY i CDL 2- 3 CAL CDL-CD/CN 6 - 16 CALIPER GR CDL-CD/CN 0-100, 100-200 12/29/83 AMOCO PRODUCTION COMPAMY MGS 17595 WELL NO. 27 12/29/83 :DE.:P:T ':iRM.'O:C~::"' R- ~ i~i!~ SP. :':' GR~--~-C'~L' , '.' ~--~ CN --C-O~R --~R ~.:..'" .....: :::: :~::~~--~' : : :;::::':::: ~3J ;;:: ~:;:: Z'*"~ :TS~O 1~'.~2.'.:' 28'-4'~..~:'~.'2 34.43 -;%] 7 27.3 6 ': ':.:.": ...::-..0 ;, 3 ~* *"* '* ~:; ~:110.'.0 ~ .~'1~..83' ~D.72~ :1:' ?5 '~, 94 - 1.38 ...... ~::~::~:::~ ~:~:26:1~':~i 1.7331'82 -1.3-~ 23.31 .~-'-:.~.....:.8~?~5'~.~-;. *:~:5.:..~0~ 15.,~.9 :~:7128.75 - 1.3823 · ~ 8 ~' .'~'~"~'~:':~G:':~."~::~: :5:'.~:~1'i~:~::1~:~ .... ~:,72 .... i'7831.19 -1.3418.71 ~.~'-(. *.' 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