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Home My WebLink About204-163MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, October 3, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC KGSF 7A SWANSON RIVER KGSF 7A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/03/2025 KGSF 7A 50-133-20538-01-00 204-163-0 G SPT 6076 2041630 1519 3426 3426 3426 3426 22 22 22 22 4YRTST P Guy Cook 8/21/2025 Testing was completed with a triplex pump and calibrated gauge. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:SWANSON RIVER KGSF 7A Inspection Date: Tubing OA Packer Depth 840 1678 1678 1675IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250820120117 BBL Pumped:0.5 BBL Returned:0.5 Friday, October 3, 2025 Page 1 of 1            Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230728 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-23 50133206350000 214093 7/16/2023 HALLIBURTON PPROF BCU-24 50133206390000 214112 7/15/2022 HALLIBURTON PPROF BRU 223-34 50283201880000 223041 7/9/2023 HALLIBURTON RMT3D KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON EPX KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON MFC KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON EPX KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON MFC KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON EPX KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON MFC MPU B-24 50029226420000 196009 7/24/2023 HALLIBURTON WFL-TMD3D MPU B-34 50029235690000 216139 7/23/2023 HALLIBURTON WFL-TMD3D MPU B-50 50029232400000 204252 7/21/2023 HALLIBURTON WFL-TMD3D MPU E-23 50029225700000 195094 6/17/2023 HALLIBURTON COILFLAG MPU F-17 50029228230000 197196 7/2/2023 HALLIBURTON COILFLAG MPU L-13A 50029223350100 223017 6/21/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON RBT PBU 11-07 50029206870000 181177 6/28/2023 HALLIBURTON RMT3D SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON EPX SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON MFC SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON EPX SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON MFC Please include current contact information if different from above. T37886 T37887 T37888 T37889 T37889 T37890 T37890 T37891 T37891 T37892 T37893 T37894 T37895 T37896 T37897 T37898 T37898 T37899 T37900 T37900 T37901 T37901 KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON EPX KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON MFC Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.01 10:05:02 -08'00' From:Regg, James B (CED) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: MIT - Swanson River KGSF 7A - 9/5/2021 Date:Tuesday, September 7, 2021 12:17:40 PM Attachments:MIT Swanson River - KGSF 7A - 2021-09-05.xlsx Swanson River KGSF-7A (PTD 2041630) Accepted test as performed Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent: Tuesday, September 7, 2021 10:51 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL] RE: MIT - Swanson River KGSF 7A - 9/5/2021 Mr Regg I updated the form with the volumes pumped and returned. Apologies for the incomplete submission. Regarding the starting and ending test pressures, I will communicate this to the field and ensure their procedures are consistent with the guidance bulletin. Concerning the test on KGSF 7A, would you like the test redone? Thanks Josh Allely Well Integrity Engineer Cook Inlet Basin – Hilcorp Alaska 907-777-8505 From: Regg, James B (CED) <jim.regg@alaska.gov> Sent: Tuesday, September 7, 2021 8:48 AM To: Josh Allely - (C) <Josh.Allely@hilcorp.com> Cc: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov> Subject: [EXTERNAL] RE: MIT - Swanson River KGSF 7A - 9/5/2021 Volumes pumped and returned? Also refer to guidance bulletin 10-02B regarding test pressures (Page 2 of attached), specifically starting and ending test pressures. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent: Tuesday, September 7, 2021 8:39 AM To: Regg, James B (CED) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: MIT - Swanson River KGSF 7A - 9/5/2021 Attached is the official report of the successful MIT performed on Swanson River KGSF 7A tested on 9/5/2021. Thanks Josh Allely Well Integrity Engineer Cook Inlet Basin – Hilcorp Alaska 907-777-8505 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2041630 Type Inj G Tubing 3000 3000 3000 3000 Type Test P Packer TVD 6077 BBL Pump 0.6 IA 204 1520 1512 1510 Interval 4 Test psi 1519 BBL Return 0.6 OA 78 78 78 78 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Hilcorp Alaska LLC Swanson River Field / Swanson River Unit / P & S Yard Pad Waived Zachary Rohr 09/05/21 Notes: Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov KGSF #7A Notes: Notes: Notes: Form 10-426 (Revised 01/2017)MIT Swanson River - KGSF 7A - 2021-09-05 (002) • 1110 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re -'� DATE: Friday,October 20,2017 P.I.Supervisor jr`ic (�1 1 '7 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC KGSF 7A FROM: Matt Herrera SWANSON RIVER KGSF 7A Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name SWANSON RIVER KGSF 7A API Well Number 50-133-20538-01-00 Inspector Name: Matt Herrera Permit Number: 204-163-0 Inspection Date: 9/26/2017 Insp Num: mitMFH170928150758 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ' KGSF 7A • ype Inj I G 'TVD 6076 ' Tubing 2907 2909 ' 2909 ' 2909 - PTD 2041630 ✓ Type Test SPT Test psi' 2313 - IA 784 2313 - 2311 " 2311 - BBL Pumped: 0.8 ",BBL Returned: 0.8 - OA 190 192 - 193 -1 192 Interval Four Year Cycle P/F Pass Notes: IA test pressure used to reflect injection psi/500 psi differential SCANNED 1 fi ;i i Friday,October 20,2017 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,October 03,2017 TO: Jim Regg _ P.I.Supervisor fei I Di5 II 7 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC KGSF 7A FROM: Matt Herrera SWANSON RIVER KGSF 7A Petroleum Inspector Src: Inspector Reviewed By:��7 P.I.Supry SCE-- NON-CONFIDENTIAL Comm Well Name SWANSON RIVER KGSF 7AAPI Well Number 50-133-20538-01-00 Inspector Name: Matt Herrera Permit Number: 204-163-0 Inspection Date: 9/28/2017 Insp Num: mitMFH170928150758 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well KGSF 7A ' (Type Inj G TVD 6076 ' Tubing 2907 2909 ' 2909 ' 2909 PTD 2041630 Type Test SPT Test psi 2313 - IA 784 2313 2311 2311 - -------------------------------------------- BBL Pumped: 0.8 BBL Returned: 0.8 OA 190 192 ' 193 ' 192 - Interval 4YRTST P/F P ,i Notes: IA test pressure used to reflect injection psi/500 psi differential CA 41 FD E.f 1 4 201s Tuesday,October 03,2017 Page 1 of 1 Image Project Well History File Cover 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. o~.(~ ~.~. - ~ ~3 Well History File Identifier Organizing (done) RES N Color Items: reyscale Items: ^ Poor Quality Originals: o,~.„e iiiumiuiiuui DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: ^ Rescan Needed II (II'I (~ II I I II I III OVERSIZED (Scannable) ^ Maps: Other Items Scannable by a Large Scanner ~4GS OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~s~ Pro -ect Proofing II I II II II I I III I I III BY: Maria Date: a a+. /s/ Scanning Preparation ~ x 30 = ~~ + ~~ =TOTAL PAGES ~~ ~''7~"7TT~~ (Count does not include cover sheet) { ,. /~ (~ BY: Maria Date: ~~ l ~ `a., l ~ ~ ~s~ I/V l 1 Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Prep ration: YES NO BY: Maria Date: ~. /~ ~s~ ~~ ~~ Stage 1 If NO in stage 1, page(s) discrepancie were found: YES NO BY: Maria Date: /sr IIIIIII Scanning is complete at this point unless rescanning is required. III II'I II I II ReScanned III IIIIII IIIII II III BY: Maria Date: ~s~ Comments about this file: Quality Checked III IIIII III II'I III P 10/6/2005 Well History File Cover Page.doc • sc - 7A 4t 0 Reg'g, James B (DOA) From: Larry Greenstein [Ireenstein @hilcorp.com] 'Fe 61(17(‘3 Sent: Monday, September 16, 2013 12:03 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Cc: Christopher Walgenbach; Bruce Hershberger; Dale Ashe; Kevin Cassidy; Jeff Allen Subject: MIT_Swanson_09-09-13 Attachments: KGSF#7A 90 day plot.xlsx; MIT Swanson 09-09-13.xls; KGSF#7A MIT chart.pdf Gentlepeople, Here is the official report of the successful MIT on the Swanson River Gas Storage well KGSF #7A PTD# 2041630 performed on 9-9-13. Larry BANNED liEL 2 3 2013 • • _ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa alaska.aov; AOGCC.Inspectors(atalaska.gov; phoebe.brooks(rialaska.aov cchris.wallace(cialaska.gov OPERATOR: Hilcorp Alaska,LLC /e / �II`7 if 3 FIELD/UNIT/PAD: Swanson River Field/SRU/P&S Yard Pad \ y DATE: 09/09/13 OPERATOR REP: Kevin Cassidy AOGCC REP: waived Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well KGSF#7A Type Inj. G , TVD 6,077' Tubing 2746 2746 2746 2746 Interval 4 P.T.D. 2041630 'Type test P Test psi 1519 - Casing 120 1524' 1516 ' 1516 ' P/F P Notes: OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi_ Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT Swanson 09-09-13.xIs • 405.(ThAsOA, C1---s *74, &Alb 3c - gr--r 1 2 .... .,,, ____1001 iieri ..._ ...._ ..s. ,, ,, 7_ 0.00,4,iwo--r____ „0. ,::: ,.. --4,„ if "la r441***P- ,-ei) 40 idol: _---t_;. .0.4_4%P ------ ,,A,A,N. °- -Porsowvir - - -4w. ,k0 :1tistd. v., - „to -,:" '7- 2,5 • 4■• '>#144 -; 11410111;- : --2-::->":4°IbtA 40:64# LI\ 40 A'-' 7'?-(f3340 II .-'-ottWN- -74-C. 0; °9 **Oil* 4414tet4V;, - i AIIIIIIT ;O:'?:* 4 tlt. ****11 al itioy ;0(2,t\ ktiv , s , p,f--- „k4404t4,4 lek, * \ ik 02,0 ry.weste* \ vitivitistk 1 % IRA bit pi* / tb, ttititas 01 ,u MI Itittellit -, -- Titiws fr bi . '-''-\\ gs,, 1- lit I \ 0 ,40 :.; rct,D)) iti _ 1 ; it§ eltifil c2 1 In •is , -i:A,* - .,_2,i) % 1\ oe, ifistrh 111 I ;PI u 81 .i\‘‘.4100104,01411Lik / Is osviss44, ct ,,,.i. 1)- es• 41:***7-# 11114111 1 ovs4 st* iiii,..1),....atv:,4 0,44/44,4,, s \p"Ploovpiravtvtss, 4#04+14 sitkftfigt4 i ■ foli,, * 440,, ,--4,.:7 Arrottivor„#4,4400+4#01441, / ,.ipe 441: •-?,90/ if 11.1.4 te,-44$0 44•41# fl ‘c) 4• 444, .#00:' --/-1.11itilipir .' 4440v "#'4**144/./ 4\4# °c)° ' '111P1106114''' 4#0/ 4414 , <.•*'\\ *-,' ,N,' 4...*- -, a = 11%-optc0 N*%•4 1i 1vs_ _ o_-___0__r C 0_ ---;-0.--,-2------ :': v/A r/t A/ 111110''' • vvCtsc V sf 7A 7-64-ik,30 Akr-r • =, Lr) 0'7 rsi CY - co cO co Lrl cr■ Cn Li- ce L) C.7 c=, csa 1.4 eNI e■ 1r4 r•-1 c",4 ••• • • Page 1 of 2 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] �_ ` (433 Sent: Monday, November 07, 2011 4:21 PM , To: Maunder, Thomas E (DOA); Regg, James B (DOA) `( . — Q Q 55 Cc: Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)],., Subject: 2011 October's SRF Tyonek 64 -5 Sand Storage Well Monitoring Report Attachments: Master Well List TIO Report 2011 11 01.xis; Master Well List TIO Report 2011 11 01.xls Hi Tom & Jim, Here is October's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 64 -5 Sand Gas Storage reservoir. Just about ready to start using the storage wells for production. They are moving very little gas into them now and withdrawal should start this month. As this storage reservoir doesn't have any monitoring wells within a 1 /2 mile radius, this report is provided as a means of monitoring the storage wells themselves. Larry „ r F/ From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, October 11, 2011 3:29 PM To: Greenstein, Larry P Cc: Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: RE: Update on 64 -5 Gas Storage Sand Larry and Chantal, • Yes, we would like this information to be provided. Regardless of no proximate wells, it is important to see the performance of the storage wells. This is especially so give the recent concern with KGSF #1 and the need for the workover. Thanks for sending the information. Tom Maunder, PE AOGCC Q From: Greenstein, Larry P [ mailt o :Greensteinlp@chevron.c_om] Sent: Monday, October 10, 2011 1:53 PM To: Maunder, Thomas E (DOA) Cc: Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: Update on 64 -5 Gas Storage Sand Tom, Based on this e -mail chain, it appears you would like a 64 -5 sand gas storage report similar to the 77 -3 sand gas storage report...even if there aren't any wells that can be used for monitoring purposes except the two storage wells themselves. 11/18/2011 • Page 2 of 2 Is that right ?? I didn't think you needed to see this report because there aren't any wells to monitor within 1 /2 mile. Sorry for the omission. It would look something like this... Notice the gap in the KGSF #1 data while the well was being worked over. Larry 11/18/2011 Plot Pressure &gate vs Time - Well KGSF #7A • 3000 20000 2500 i i lt /' 1 ''` 5/8" .V // 1 - Tubing Vol Inj - Vol Prod 15000 2000 — 1 II' L LL 171 15 00 iI � _ _ g v 10000" ti 1000 • 5000 500 • 1 7 Y 0 0 N 7 '7 E m N O O O (` 2 N in co r r co O) O O O O O 0 0 Date 7" rTsi7P Tubing VoTinj Vol Prod TIO Report 10/31 /11 100 85 2756 0 0 10/30/11 100 85 2753 0 0 Data Sheet 10/28/11 100 85 2759 0 0 10/27/11 00 85 2753 0 10/26/11 00 85 2760 0 0 KGSF #7A 10/25/11 00 85 2757 0 0 10/24/11 00 85 2767 0 0 10/23/11 00 85 2765 0 0 FLOWING 10/22/11 00 85 2771 0 0 10/21 /11 00 85 2772 10/20/11 00 85 2797 327 0 Permit # 2041630 10/19/11 00 85 2814 0 0 10/18/11 25 86 2814 0 0 10/17/11 150 87 2818 0 0 API # 50- 133 - 20538 -01 10/16/11 00 88 2841 0 0 10/15/11 50 94 2867 5337 0 10/14/11 50 95 2970 9581 05/02/2011 to 11/01/2011 10/13/11 50 92 2780 4276 10/12/11 150 90 2732 1749 0 10/11/11 230 87 2755 877 0 10/10/11 " 170 87 2795 2949 10/09/11 175 87 2852 8763 10/08/11 175 87 2791 9653 0 10/07/11 150 87 2650 10088 10/06/11 150 87 2560 1277 10/05/11 100 82 2576 0 0 10/04/11 100 82 2585 0 0 10/03/11 99 81 2581 0 0 10/02/11 100 ` 80 2586 0 0 10/01/11 00 80 2586 0 0 09/30/11 100 80 2589 0 0 09/29/11 100 82 2585 0 0 09/28/11 100 82 2580 0 0 09/27/11 100 82 2587 0 0 09/26/11 100 g ri i . 82 2587 0 0 09/25/11 100JMIL 82 2588 0 0 11/18/2011 8:43 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 11 01.xIs KGSF #7A • • Page 1 of Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Monday, October 10, 2011 1:53 PM To: Maunder, Thomas E (DOA) Cc: Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: Update on 64 -5 Gas Storage Sand Attachments: Master Well List TIO Report 2011 10 01.xls X)L-k-1,(0 Tom, Based on this e-mail chain, it appears you would like a 64 -5 sand gas storage report similar to the 77 -3 sand gas storage report... even if there aren't any wells that can be used for monitoring purposes except the two storage wells themselves. Is that right ?? I didn't think you needed to see this report because there aren't any wells to monitor within 1/2 mile. Sorry for the omission. It would look something like this... Notice the gap in the KGSF #1 data while the well was being worked over. Larry From: Maunder, Thomas E (DOA) [ mailto:tom.maunder @alaska.gov] Sent: Friday, April 08, 2011 11:24 AM To: Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Cc: Eastham, Kevin (KEastham); Greenstein, Larry P; Whitacre, Dave S Subject: RE: Update on 64 -5 Gas Storage Sand Chantal, et al, Thanks for the information regarding "other penetrations ". I would presume you have the injection /production pressure /rate information similar to what is submitted for Pretty Creek 4 and 42 -05X and 42 -05Y? That is the information I would like submitted. Thanks in advance. Tom Maunder, PE AOGCC 13 From: Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] [mailto:WalshC @chevron,com] Sent: Friday, April 08, 2011 11:15 AM To: Maunder, Thomas E (DOA) Cc: Eastham, Kevin (KEastham); Greenstein, Larry P; Whitacre, Dave S Subject: Update on 64 -5 Gas Storage Sand Tom, 11/8/2011 • • Page 2 oft The data you requested for the wells around KGSF 1 doesn't exist. The wells in the 1 /2 mile radius area are abandoned or isolated from the gas storage sand. We have finished our review of the spinner /temperature /pressure Togs. We received input from Halliburton log specialists as well. The sticky substance in the well bore, combined with what we are calculating as a flow rate below the sensitivity of the production tools, renders the production logs inconclusive. This analysis gave us no insight to the wellbore. with you prior to moving to the next step. are formulating a forward plan and will discuss y p g . The 64 -5 sand is p not currently being utilized for production or injection purposes. Chantal From: Eastham, Kevin (KEastham) Sent: Friday, April 08, 2011 8:21 AM To: Greenstein, Larry P Cc: Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: RE: wells around 64 5 That's correct, Larry. There are no wells within %2 mile that would work for monitoring the 64 - sand. From: Greenstein, Larry P Sent: Friday, April 08, 2011 7:42 AM To: Eastham, Kevin (KEastham) Cc: Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: RE: wells around 64 5 What this tells me is that there aren't any wells within 1/2 mile that are connected to surface gauges to use for monitoring the 64 -5 sand (unless a plug or cement has failed)... correct ?? Larry From: Eastham, Kevin (KEastham) Sent: Thursday, April 07, 2011 1:19 PM To: Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Cc: Greenstein, Larry P Subject: RE: wells around 64 5 At the 64 -5 reservoir level, the following wells are within a 1/2 mile radius of KGSF #1 & #7A: Attached is a map showing wells and %2 mile radius. (All wells below are SRU) 34 -28, 314 -27, 41 -28, 212 -27, 12 -27. Notes: KGSF 2 was sidetracked out of 12 -27 targeting the 62 -5 sand which is above the 64 -5 storage sand in #1 & #7A. Also, 314 -27, 41 -28, and 12 -27 /KGSF 2 have all been P &A'd. Similar to KGSF 2, KGSF 3 is within %2 mile radius, but targeted the shallower 62 -5 sand as well. In 212 -27, the 64 -5 is beneath a cemented -in packer and two plugs (w/ cement on top of each) In 34 -28, the 64 -5 is beneath a cement packer. 11/8/2011 Plot Pressure & • ate vs Time - Well KGSF #7A - 20000 2500 _ _ —T' •9 5/8" 1 Tubing •Vol In] •Vol Prod , y 2000 _ 15000 1500 LL N ti v 10006 ! 1000 —_ 5000 500 , I.. 0 0 O O 0? M M N r O O O 0 0 CO 0 0 Date 7" Tubing Vol Inj Vol Prod TIO Report 10/01/11 200 2586 0 0 09/30/11 100 2589 0 0 Data Sheet 09/29/11 100 2585 0 0 09/28/11 100 2580 0 0 09/27/11 100 2587 0 0 KGSF #7A 09/26/11 100 2587 0 0 09/25/11 100 2588 0 0 09/24/11 100 2593 0 0 FLOWING 09/23/11 100 2596 0 0 09/22/11 100 2600 0 0 09/21/11 100 2614 0 Permit # 2041630 09/20/11 100 2582 0 0 09/19/11 100 2576 0 0 09/18/11 100 2557 0 0 API # 50- 133 - 20538 -01 09/17/11 100 2527 0 0 09/16/11 125 2514 0 0 09/15/11 100._ 82 2502 0 0 04/01/2011 to 10/01/2011 09/14/11 100 83 2464 0 0 09/13/11 100 85 2440 0 0 09/12/11 100 88 2418 0 0 09/11/11 100 88 2406 0 0 09/10/11 100 88 2398 0 0 09/09/11 100 88 2428 4779 09/08/11 100 82 2393 1157 0 09/07/11 100 82 2391 0 0 09/06/11 100 140 2397 0 0 09/05/11 100 140 2399 0 0 09/04/11 100 140 2397 0 2 09/03/11 100 140 2397 0 0 09/02/11 100 81 2391 0 0 09/01/11 100 81 2391 0 0 08/31 /11 100 81 2390 0 0 08/30/11 100 81 2391 0 0 08/29/11 100 81 2450 0 0 08/28/11 100 ° 82 2398 0 0 08/27/11 100 81 2392 0 0 11/8/2011 1:59 PM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 10 01.xIs KGSF #7A • • Chevron Chantal R Walsh Union Oil Company of California 110. Petroleum Engineer, P.E. 3800 Centerpoint Dr., Suite 100 Anchorage, AK 99503 1%0 Tel: 907-263-7627 alshc the Email 7- 263 -7627 on.com '' AtG 1 8 201U August 12, 2011 RECEIVED AUG 1 7011 Mr. Dan Seamount, Chairman Meke OA & GasCes.Gemnission Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anthem Anchorage, AK 99501 -3539 RE: 2011 Annual Material Balance Calculations of Production and Injection Volumes: Kenai Gas Storage Facility #1 (KGSF #1), Swanson River Field Dear Commissioner Seamount: a 0 IL ` - S Attached for Alaska Oil and Gas Conservation Commission (AOGCC) review is the 2011 annual material balance calculation of production and injection volumes for the Kenai Gas Storage Facility #1 (KGSF #1), as required per Storage Injection Order #2A. This material balance includes all primary production from the Tyonek 64 -5 reservoir (via the SRU 43 -28 wellbore), as well as all storage operations from the two gas storage wells, KGSF #1 and KGSF #7A. Primary production occurred from December 1998 through May 2001 and storage operations are on -going since June 2001. Attachment #1 is a table of monthly gas production and injection volumes for KGSF #1 (formerly SRU 43 -28) and KGSF #7A, from the commencement of primary production, through August 12, 2011. Pressures from the Tyonek 64 -5 reservoir have been measured /estimated from both downhole pressure buildups and from surface shut -in tubing pressures. The surface readings were then converted to downhole pressures at a common datum of 6,395 ft TVD. These data points are tabulated in Attachment #2 and plotted versus the net cumulative production (production less injection) on the standard P over Z plot, shown in Attachment #3. As noted in previous Annual Material Balance reports, Attachment #3 shows that the early injection cycle pressures deviated above the straight line path established by the primary depletion pressure points. Following the primary production and injection cycle, the next two or three cycles (production & injection) show a consistent trend of the pressure /cumulative production data points migrating further left of the straight line path established by the primary depletion pressure points. Over the last four years, cycles from 2007 - 2010 were fairly consistent, indicating continued reservoir confinement of the gas storage volume. The last injection /production season, 2010 - 2011, showed a deviation from the previous years' trends. At the end of the production cycle the KGSF #1 well had water in the well bore which was not MidContinent /Alaska /Chevron North America Exploration and Production www.chevron.com • • . present in the KGSF #7A well. This led us to suspect a mechanical issue with KGSF #1. We are currently working over this well, and hope to resolve the issues. If you or your staff has any questions regarding this annual report, please contact me at 263- 7627. Sincerely, C2L-4- lilt -LL Chantal Walsh Petroleum Engineer, P.E. Attachments: 1. KGSF #1 Facility Monthly production and injection volumes 2. Tyonek 64 -5 Sand POZ Data 3. KGSF #1 Facility (Tyonek 64 -5 Sand) - P/Z vs Cumulative Production Plot CC: Whitacre, Dave KGSF #1 Well File KGSF #7 Well File MidContinent/Alaska /Chevron North America Exploration and Production http: / /www.chevron com • • ATTACHMENT #1 KENAI GAS STORAGE FACILITY #1 (KGSF #1) MONTHLY PRODUCTION AND INJECTION VOLUMES • AMENDED - 08/18/11 SRU 43 -281 KGSF #1 1 KGSF #7A 1 I Tyonek 64 -5 Sand Totals 1 Monthly Monthly Monthly Monthly Net Voidage Total Gas Gas Gas Gas Gas (Prod -Inj) Inventory Inj. Prod. Inj. Prod. Cum for POZ (Gas -ln- Place) Month MCF MCF IMF MCF MCF MCF 1,544,000 Dec -98 0 55,137 55,137 1,488,863 Jan -99 0 79,404 134,541 1,409,459 Feb -99 0 64,367 198,908 1,345,092 Mar -99 0 73,920 272,828 1,271,172 Apr -99 0 62,180 335,008 1 ,208,992 May -99 0 76,912 411,920 1,132,080 Jun -99 0 76,903 488,823 1,055,177 Jut -99 0 72,268 561,091 982,909 Aug -99 0 60,311 621,402 922,598 Sep -99 0 48,667 670,069 873,931 Oct -99 0 42,056 712,125 831,875 Nov -99 0 39,385 751,510 792,490 Dec -99 0 33,783 785,293 758,707 Jan -00 0 39,890 825,183 718,817 Feb -00 0 20,895 846,078 697,922 Mar -00 0 38,219 884,297 659,703 Apr -00 0 35,729 920,026 623,974 May -00 0 22,502 942,528 601,472 Jun -00 0 8,627 951,155 592,845 Jul -00 0 30,397 981,552 562,448 Aug -00 0 56,660 1,038,212 505,788 Sep -00 0 30,505 1,068,717 475,283 Oct -00 0 29,330 1,098,047 445,953 Nov -00 0 48,633 1,146,680 397,320 Dec -00 0 29,741 1,176,421 367,579 Jan -01 0 46,236 1,222,657 321,343 Feb -01 0 47,777 1,270,434 273,566 Mar -01 0 37,213 1,307,647 236,353 Apr -01 0 24,719 1,332,366 211,634 May -01 0 6,196 1,338, 562 205,438 Jun -01 106,800 0 1,231,762 312,238 Jul -01 219,660 0 1,012,102 531,898 Aug -01 226,151 0 785,951 758,049 Sep -01 197,762 1,331 589,520 954,480 Oct -01 44,964 60,382 604,938 939,062 Nov -01 73,130 142,418 674,226 869,774 Dec -01 28,281 159,046 804,991 739,009 Jan -02 134,429 47,741 718,303 825,697 Feb -02 102,768 65,400 680,935 863,065 Mar -02 250,716 4,507 434,726 1,109,274 Apr -02 107,164 51,031 378,593 1,165,407 May -02 89,218 16,147 305,522 1,238,478 Jun -02 106,081 3,868 203,309 1,340,691 0: WAU\ MCBU \Alaska\Depts\AssetDev \CIGas \Gas CFT\Openniind \Swanson\Swanson RiverUnit \KGSF #1\Surveys\Pressures\AOGCC AMB Rpt\20101KGSF #1 #7 8- 12- 11,xls • • ATTACHMENT #1 KENAI GAS STORAGE FACILITY #1 (KGSF #1) MONTHLY PRODUCTION AND INJECTION VOLUMES AMENDED - 08/18/11 I SRU 43 -28 / KGSF #1 ! 1-KGSF #7A I I Tyonek 64 -5 Sand Totals f Monthly Monthly Monthly Monthly Net Voidage Total Gas Gas Gas Gas Gas (Prod - Inj) inventory Inj. Prod. Inj. Prod. Cum for POZ (Gas -in- Place) Month MCF MCF MCF MCF MCF MCF Jul -02 66,737 18,479 155,051 1,388,949 Aug -02 19,263 140,660 276,448 1,267,552 Sep -02 73,737 60,587 263,298 1,280,702 Oct -02 0 272,859 536,157 1,007,843 Nov -02 0 193,970 730,127 813,873 Dec -02 701 149,810 879,236 664,764 Jan -03 0 125,601 1,004,837 539,163 Feb -03 0 77,767 1,082,604 461,396 Mar -03 0 58,978 1,141,582 402,418 Apr -03 0 40,867 1,182,449 361,551 May -03 0 31,252 1,213,701 330,299 Jun -03 0 23,977 1,237,678 306,322 Jul-03 0 17,937 1,255,615 288,385 Aug -03 0 9,611 1,265,226 278,774 Sep -03 173,513 0 1,091,713 452,287 Oct -03 298,780 0 792,933 751,067 Nov -03 287,672 0 505,261 1,038,739 Dec -03 264,137 1,456 242,580 1,301,420 Jan -04 30,651 56,710 268,639 1,275,361 Feb -04 42,508 56,096 282,227 1,261,773 Mar -04 18,083 153,053 417,197 1,126,803 Apr -04 46,661 49,678 420,214 1,123,786 May -04 173,756 1,811 248,269 1,295,731 Jun -04 117,522 0 130,747 1,413,253 Jul -04 3,936 0 126,811 1,417,189 Aug -04 0 0 126,811 1,417,189 Sep -04 83,061 0 43,750 1,500,250 Oct -04 20,297 37,277 0 38,408 99,138 1,444,862 Nov-04 100,085 46,394 114,424 0 - 68,977 1,612,977 Dec -04 1,372 5,222 1,523 3,687 - 62,963 1,606,963 Jan -05 35,347 66,988 771 60,345 28,252 1,515,748 • Feb -05 31,778 82,231 3,217 114,252 189,740 1,354,260 Mar -05 43,588 55,099 1,211 78,836 278,876 1,265,124 Apr -05 28,607 35,501 8,081 19,522 297,211 1,246,789 May -05 32,140 88,209 18,126 101,966 437,120 1,106,880 Jun -05 116,349 2,892 60,975 2,436 265,124 1,278,876 Jul -05 79,421 4,803 96,626 740 94,620 1,449,380 Aug -05 56,470 60,228 61,086 25,369 62,661 1,481,339 Sep -05 75,912 16,301 8,356 11,394 6,088 1,537,912 Oct -05 44,207 68,184 13,635 94,247 110,677 1,433,323 Nov -05 68,267 45,043 65,065 62,387 84,775 1,459,225 Dec -05 68,931 29,178 97,297 20,153 - 32,122 1,576,122 Jan -06 24,400 154,713 21,678 176,620 253,133 1,290,867 Feb -06 123,934 83,744 191,098 99,388 121,233 1,422,767 0:\ NAU\ MCBUVAlaska \Depts\AssetDev \ClGas \Gas CFT10penrnind \Swanson \Swanson RiverUnit ■KGSF #1 \Surveys \Pressures\AOGCC AMB Rpt\2010 \KGSF #1 #7 5- 12- 11.xls • • • ATTACHMENT #1 KENAI GAS STORAGE FACILITY #1 (KGSF #1) MONTHLY PRODUCTION AND INJECTION VOLUMES AMENDED - 08/18/11 1 SRU 43 -281 KGSF #1 1 I KGSF #7A ( I Tyonek 64 -5 Sand Totals 1 Monthly Monthly Monthly Monthly Net Voidage Total Gas Gas Gas Gas Gas (Prod - Inj) Inventory Inj. Prod. inj. Prod. Cum for POZ (Gas -In- Place) Month MCF MCF MCF MCF MCF MCF Mar -06 54,898 145,807 35,421 147,941 324,662 1,219,338 Apr -06 131,597 34,604 8E,982 19,989 161,676 1,382,324 May -06 106,658 4,759 110,253 26,840 - 23,636 1,567,636 Jun -06 50,042 675 14,923 482 - 87,444 1,631,444 Jul -06 0 79,130 0 36,777 28,463 1,515,537 Aug -06 63,182 130 18 ,045 0 - 50,634 1,594,634 Sep -06 45,366 0 18,939 0 - 114,939 1,658,939 Oct -06 18,013 58,243 42,099 7,334 - 109,474 1,653,474 Nov -06 30,592 82,779 24,730 98,430 16,413 1,527,587 Dec -06 55,743 17,160 102,029 14,959 - 109,240 1,653,240 Jan -07 21,586 59,415 34,936 91,755 - 14,592 1,558,592 Feb -07 7,025 59,181 41,275 106,823 103,112 1,440,888 Mar -07 15,008 58,203 83,830 92,486 154,963 1,389,037 Apr -07 75,784 6,866 185,316 8,751 - 90,520 1,634,520 May -07 8,872 23,772 32,655 55,100 - 53,175 1,597,175 Jun -07 11,714 0 740 134 - 65,495 1,609,495 Jul -07 7,350 0 0 0 - 72,845 1,616,845 Aug -07 1,767 891 230 0 - 73,951 1,617,951 Sep -07 0 253 0 240 - 73,458 1,617,458 Oct -07 9,706 18,077 11,553 6,168 - 70,472 1,614,472 Nov -07 13,638 40,135 7,563 8,237 - 43,301 1,587,301 Dec -07 8,443 61,237 3,820 132,338 138,011 1,405,989 Jan -08 20,892 75,223 751 88,161 279,752 1,264,248 Feb -08 8,162 54,785 8,134 83,015 401,256 1,142,744 Mar -08 94 1,014 0 4,872 407,048 1,136,952 Apr -08 46,111 3,360 11,372 0 352,925 1,191,075 May -08 88,929 12,687 218,106 12,037 70,614 1,473,386 Jun -08 20,487 4,309 32,741 0 21,695 1,522,305 Jul -08 8,057 0 2,181 0 11,457 1,532,543 Aug -08 19,270 484 0 0 -7,329 1,551,329 Sep -08 5,064 1,530 0 820 - 10,043 1,554,043 Oct -08 15,323 46,294 2,459 5,913 24,382 1,519,618 Nov -08 3,361 95,514 0 82,213 198,748 1,345,252 Dec -08 10,856 92,077 7,285 162,128 434,812 1,109,188 Jan -09 25,898 54,278 31,732 114,632 546,092 997,908 Feb -09 26,994 50,408 42,968 76,145 602,683 941,317 Mar -09 25,801 14,995 10,298 22,451 604,030 939,970 Apr -09 158,105 989 236,991 608 210,531 1,333,469 May -09 36,786 103 134,138 27 39,737 1,504,263 Jun -09 43,429 519 103,093 299 - 105,967 1,649,967 Jul -09 0 0 0 274 - 105,693 1,649,693 Aug -09 0 39,305 45,129 228 - 111,289 1,655,289 Sep -09 0 25,743 24,073 146 - 109,473 1,653,473 Oct -09 0 0 28,450 271 - 137,652 1,681,652 O:\NAUIMCBU' Alaska \DeptsAAssetDev\ClGas \Gas CFT\Openmind \Swanson \Swanson RiverUnit KGSF #1 \Surveys \Pressures'AOGCC AMB Rpt\20101KGSF #1 #7 8- 12- 11.xls • 0 ATTACHMENT #1 KENAI GAS STORAGE FACILITY #1 (KGSF #1) MONTHLY PRODUCTION AND INJECTION VOLUMES AMENDED - 08/18/11 SRU 43 -281 KGSF #1 1 I #7A I I Tyonek 64 -5 Sand Totals I Monthly Monthly Monthly Monthly Net Voidage Total Gas Gas Gas Gas Gas (Prod - Inj) Inventory Inj, Prod. Inj, Prod. Cum for POZ (Gas -In- Place) Month MCF MCF MCF MCF MCF MCF Nov -09 550 15,175 34,114 33,063 - 124,078 1,668,078 Dec-09 137 8,539 11,074 66,621 - 60,129 1,604,129 Jan -10 10,556 36,797 0 12,397 - 21,491 1,565,491 Feb -10 0 48,589 17 2,232 29,313 1,514,687 Mar -10 0 64,473 0 54,969 148,755 1,395,245 Apr -10 0 13,709 135 19,853 182,182 1,361,818 May -10 0 15,589 10,554 27,926 215,143 1,328,857 Jun -10 384 4,530 189 7,769 226,869 1,317,131 Jul -10 1,616 0 0 490 225,743 1,318,257 Aug -10 101,371 0 100,659 0 23,713 1,520,287 Sep -10 139,173 100 164,053 86 - 279,327 1,823,327 Oct -10 55197 12608 45,549 8,241 - 359,224 1,903,224 Nov -10 56236 46322 46,917 40,527 - 375,528 1,919,528 Dec -10 15497 137723 25,327 165,640 - 112,989 1,656,989 Jan -11 3983 187449 7,665 194,272 257,084 1,286,916 Feb -11 0 113321 0 158,649 529,054 1,014,946 Mar -11 0 20680 0 92,628 642,362 901,638 Apr -11 6736 1922 0 502 638,050 905,950 May -11 0 0 52,265 0 585,785 958,215 Jun -11 0 0 444,594 0 141,191 1,402,809 I O:\ NAU\ MCBU \Alaska\Depts\AssetDev\ClGas \Gas CFT\Openrnind \Swanson \Swanson RiverUnit\KGSF #1 ■Surveys \Pressures'AOGCC AMB Rpt\2010\KGSF #1 #7 8- 12- 11.xis NW ATTACHMENT #2 Tyonek 64 -5 Sand POZ DATA Kenai Gas Storage Facility #1 (KGSF #1) Wells: KGSF #1 & KGSF #7A (Date 1Type Test 1 Gauge Depth, ft 1 Cum, bcf 1 TbgP, psia 1 Res P, psia 1 Z 1 P/Z (Comments ' PRIMARY PRODUCTION 12/5/1998 SITP 0 0 2850 3306 0 8782 3764 SITP 7/27/1999 SITP 6395 0,561 1775 2059 0,8586 2398 SITP 9/9/2000 BHP buildup 6395 1.069 882 1100 0.9017 1220 PBU w/ Gauges FL — 6195' 2/20/2001 SITP 0 1 270 540 626 0.9396 667 SITP 6/9/2001 SITP 0 1.339 380 441 0 9566 461 SITP 2001 INJECTION CYCLE 6/9/2001 SITP 0 1339 380 441 0,9566 461 SITP 7/11/2001 SITP 0 1 148 875 1015 0.9078 1118 21 hr SITP after 618 hr injection 9/18/2001 SITP 0 0 673 1820 2111 0 8578 2461 4 hr SITP poor to flow due to SHP ESD 9/20/2001 SITP 0 0 678 1810 2099 0.8580 2447 24 hr SITP after 1 day of flow on 9/19 at 5.5 mmcfd 10/9/2001 SITP 0 0,572 1980 2297 0 8562 2682 8 day SITP during C12 restaging 2002 INJECTION CYCLE 10/9/2001 SITP 0 0 572 1980 2297 0.8562 2682 8 day SITP during C12 restaging 4/5/2002 SITP 0 0 400 2280 2645 0 8584 3081 15 hour SITP 7/12/2002 SITP 0 0 190 2620 3039 0 8680 3501 SITP 7/26/2002 SITP 0 0 200 2630 3050 0 8684 3513 SITP 2002/2003 PRODUCTION CYCLE 7/26/2002 SITP 0 0 200 2630 3050 0 8684 3513 SITP 12/5/2002 SITP 0 0 740 1415 1641 0,8709 1884 SITP (65 hr SI) 7/25/2003 SITP 0 1 252 224 260 0 9739 267 SITP from surf PBU 2003 INJECTION CYCLE I 7/25/2003ISITP 0 1 252 224 260 0,9739 267 SITP from surf PBU 12/29/2003 SITP 0 0,254 2440 2829 0 8620 3282 SI duranon = 19 hrs At shut in = 2 hrs, 2440 psig SITP, Ignores FL 2003/2004 PRODUCTION CYCLE I 12/29/2003 SITP 0 0 254 2440 2829 0 8620 3282 SI duration = 19 hrs At shut m = 2 hrs, 2440 psig SITP, Ignores FL 4/28/2004 SITP 0 0 445 2075 2406 0.8562 2810 SITP - 24 hr 2004 INJECTION CYCLE 4/28/2004 SITP 0 0 445 2075 2406 0 8562 2810 SITP - 24 hr 7/14/2004 SITP 0 0 153 2565 2974 0.8660 3435 SITP - 12 day 12/5/2004 SITP 0 -0 082 2865 3322 0 8789 3780 SITP- 4day 2004/2005 PRODUCTION CYCLE I 12/5/2004 SITP 0 -0,082 2665 3322 0 8789 3780 SITP- 4day 6/8/2005 SITP 0 0 396 2080 2412 0,8562 2817 SITP - 6 hr 2005 INJECTION CYCLE 6/8/2005 SITP 0 0 396 2080 2412 0 8562 2817 SITP - 6 hr 8/8/2005 SITP 0 0,022 2828 3279 0.8771 3739 SITP - 1 hr 12/30/2005 0 -0 044 2786 3231 0,8751 3692 SITP - 3 days 2005/2006 PRODUCTION CYCLE I 12/30/2005 0 -0 044 2786 3231 0 8751 3692 SITP - 3 days 3/22/20061 SITP 0 0 396 I 1905 2209 0 8567 2579 SITP - < 1 day (KGSF #7a) 2006 INJECTION CYCLE 3/22/2006 SITP 0 0 396 1905 2209 0.8567 2579 SITP - < 1 day (KGSF #7a) 7/10/2006 SITP 0 -0 100 2815 3264 0 8764 3725 SITP - 10 days 8/14/2006 SITP 0 -0 023 2687 3116 0 8707 3579 SITP -19 days (KGSF 47a) 9/30/2006 SITP 0 -0 127 2815 3264 0 8764 3725 SITP -12 day (KGSF #1) 2006/2007 PRODUCTION CYCLE 9/30/2006 SITP 0 -0.127 2815 3264 0.8764 3725 SITP -12 day (KGSF 41) 12/4/2006 SITP 0 -0 049 2665 3090 0 8698 3553 SITP -18 5 hrs (KGSF #7a) 1/10/2007 SITP 0 -0,003 2450 2841 0 8623 3295 S1TP -9 hrs (KGSF 41) 3/26/2007 SITP 0 0.167 2231 2587 0 8576 3017 SITP -4 day (KGSF 41) 2007 INJECTION CYCLE 3/26/2007 SITP 0 0.167 2231 2587 0.8576 3017 SITP -4 day (KGSF 41) 4/27/2007 SITP 0 -0 117 2828 3279 0.8771 3739 SITP -8 day (KGSF #1) 6/4/2007 SITP 0 -0 065 2711 3144 0 8717 3606 SITP -5 day (KGSF #1) 9/11/2007 SITP 0 -0.088 2717 3151 0 8720 3598 SITP -27 day (KGSF #l) 2007/2008 PRODUCTION CYCLE 9/11/2007 SITP 0 -0 088 2717 3151 0 8720 3598 SITP -27 day (KGSF #1) 12/2/2007 SITP 0 -0 043 2604 3005 0 8669 3466 SITP - 6 days (KGSF 67A) - PMW 1/17/2008 SITP 0 0 243 2078 2397 0 8562 2800 SITP - 8 days (KGSF 47A) 4/8/2008 SITP 0 0 407 1760 2026 0.8592 2358 SITP - 37 days (KGSF 47A) • 2008 INJECTION CYCLE 4/8/2008 SITP 0 0.407 1760 2026 0 8592 2358 SITP - 37 days (KGSF #7A) 5/2/2008 SITP 0 0.353 1925 2218 0 8566 2567 SITP - —2 months (KGSF #7A) 7/1/2008 SITP 0 0.022 2643 3049 0 8684 3494 SITP - 22 day (KGSF 41) 7/28/2008 SITP 0 0 015 2648 3055 0 8686 3517 SITP - 22 days (KGSF #1) 9/16/2008 SITP 0 -0 005 2664 3073 0,8692 3535 SITP - 22 days (KGSF #1) 9/30/2008 SITP 0 -0 010 2670 3080 0 8694 3543 SITP - 5 days (KGSF 41) 8/15/201112.54 PMO \ NAU/ MCBU \Alaska\Depts\AssetDev \CIGas \Gas CFT\Openmwd \ Swanson \Swanson RtverUmt \KGSF #1 \Surveys\Pressures\AOGCC AMB Rpt\2011\KGSF #1 & 47A 64 -5 Sd ALL POZ 7-11 - 11.x1s64 -5 POZ Data r ATTACHMENT #2 • Tyonek 64 -5 Sand POZ DATA Kenai Gas Storage Facility #1 (KGSF #1) Wells: KGSF #1 & KGSF #7A (Date Type Test 1 Gauge Depth, ft 1 Cum, bcf 1 TbgP, psia 1 Res. P, psia 1 Z 1 P/Z Comments 2008/2009 PRODUCTION CYCLE 9/30/2008 SITP 0 -0,010 2670 3080 0 8694 3543 SITP - 5 days (KGSF 41) 1/16/2009 SITP 0 0.576 1392 1599 0.8728 1832 SITP - 2 5 days (KGSF 61) 2/19/2009 SITP 0 0,626 1376 1579 0.8737 1807 SITP - 24 hr SI (KGSF 61 & 67A) 2009 INJECTION CYCLE 2/19/2009 SITP 0 0,626 1376 1579 0,8737 1807 SITP - 24 hr SI (KGSF 61 & #7A) 6/14/2009 SITP 0 -0 065 2781 3209 0.8742 3671 SITP - 10 days SI (KGSF 61) 7/13/2009 S1TP 0 -0 106 2850 3287 0 8774 3746 SITP - 14 days SI (KGSF 61) 8/10/2009 SIT? 0 -0 106 2828 3262 0 8764 3722 SITP - 42 days SI (KGSF #7A) 2009/2010 PRODUCTION CYCLE 10/12/2009 SITP 0 -0.109 2774 3218 0 8746 3680 SITP - 23days (KGSF 67A) 1/24/2010 SITP 0 -0 012 2630 3036 0.8679 3498 SITP - 4 days (KGSF 61) 3/8/2010 SITP 0 0 035 2528 2919 0 8644 3377 SITP - 4 day SI (KGSF 61 & #7A) 5/13/2010 SITP 0 0 181 2231 2576 0 8575 3004 SITP - 24 hrs SI (KGSF 61) 2010 INJECTION CYCLE 5/13/2010 SITP 0 0 181 2231 2576 0 8575 3004 SITP - 24 hrs SI (KGSF 61) 8/11/2010 SITP 0 0,176 2313 2671 0,8588 3110 SITP - 14 da s SI (KGSF #1) 10/20/2010 SITP 0 -0359 3134 3626 0,9042 4009 2010/2011 PRODUCTION CYCLE 10/20/2010 SITP 0 -0.359 3134 3626 0 8842 4009 12/8/2010 SITP 0 -0.349 3021 3500 0 8775 3895 SITP - 24 hours 12/21/2010 SITP 0 -0,200 2727 3176 0.8626 3577 1 day SI 3/1/2011 SITP 0 0 533 1123 1310 0,8799 1472 48 hr SI 3/21/2011 Guage PBU 5300 0.643 1171 0,8895 1316 2011 INJECTION CYCLE 3/21/2011 Guage PBU 5300 0 643 1171 0 8895 1316 7/4/2011 Guage PBU 5300 0 092 2720 0 8628 3152 72 hour shut m 7/31/2011 WI-IP 0 0 092 2395 2796 0.8644 3235 3 weeks shut in 8/15/201112 54 PMO.\ AU \MCBU\Alaska\Depts\AssetDev \CIGas \Gas CFT\Openmind \ Swanson \Swanson ILverUnit \KGSF #I\ Surveys \Pressures\AOGCC AMB Rpt\201l\ iGSF #1 & #7A 64 -5 Sd ALL POZ 7-11 - 11.x1s64-5 POZ Data • ATTACHMENT #3 KGSF #1 FACILITY (Tyonek 64 -5 Sand) - P/Z vs Cumulative Production Plot 4500 - -- -0— Primary 4000 - - -- - -tr -'01 Inj cycle ••••03 Prod Cycle 3500 `,, ;�, ,. - — - —-03 Inj Cycle ♦ 08 Prod Cycle • 3000 -_. _ —. ___. — _ — - - �- 08 Inj Cycle _ :111111111111116 2500 - - - -- -' \ 7 - - -. — ..__... - -- -40-09 Prod Cycle - --6— 09 Inj Cycle 7 \ N .%. . a 2000 -- - - N w ♦ 1: ::1e 1500 - -- - - -- _. - - - -- f - t 1 1 Prod/Inj Cycle 1000 — ` _ \ • 500 -- - - - - -- - - - - -- ♦� _ I ' ` -0.4 -0.2 0 0.2 0.4 0.6 0.8 1 1.2 1.4 1.6 Cumulative Gas Produced (Bct) O: \NAU \MCBU \Alaska \Depts\AssetDev \CIGas \Gas CFT \Openmind \Swanson \Swanson RiverUnit \KGSF #1 \Surveys \Pressures\AOGCC AMB Rpt \2011 \KGSF #1 & #7A 64 -5 Sd ALL POZ 7- 11- 11.xls Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) /' ` , o b g Sent: Monday, February 07, 2011 2:04 PM � Q To: McMains, Stephen E (DOA) Cc: Davies, Stephen F (DOA) — Subject: 77 -3 Gas Storage at Swanson River -Pool Code 772805 Steve, Further to the work begun earlier regarding the appropriate pool classification of Tyonek gas associated with the 64 -5 and 77 -3 storage projects, the 64 -5 [772803] and 77 -3 [772805] are distinct Tyonek sand intervals so the volume accounting needs to be separate. The matter is a little further complicated since there also is an undefined Tyonek pool code at Swanson [772500]. So far as I am aware, the only wells remaining to be reconciled are 42A -05 (180 -106) and 42B -05 (182 -199). Both wells were originally Hemlock oil producers and the Hemlock was plugged with the wells being completed in the 77 -3 sand. 42B -05 was converted to GSTOR 11/7/05. First storage injection is reported in 12/05. First gas production is reported 11/05. All gas volumes are reported to the 64 -5 pool, this should be changed to the 77 -3. 42A -05 is a little more complicated. There is no record of any gas having been injected for storage. The Hemlock was plugged and the well perforated in the 77 -3 in June 2004. It appears that all gas produced from then until the well was converted to GSTOR on 10/1/05 was credited to the undefined Tyonek Pool code [772500]. Fairly regular /continuous production is reported up through 11/05 (14 days). No production is reported in 12/05 and only 7 days in 01/06. Again, all Tyonek gas from this well should be against the 77 -3 pool code [772805]. Please let me know if further information is needed. It is probably appropriate to put a copy of this message in each well file. Tom Maunder, PE Sr. Petroleum Engineer MAR 0 9 2011 3/7/2011 DATA SUBMITTAL COMPLIANCE REPORT 6/21!2010 Permit to Drill 2041630 Well Name/No. SWANSON RIVER KGSF 7A Operator UNION OIL CO OF CALIFORNIA API No. 50-133-20538-01-00 MD 6530 TVD 6530 Completion Date 9/2/2004 Completion Status GSTOR Current Status GSTOR UIC REQUIRED INFORMATION Mud Log No Samples No Directional Survey / N6~ DATAINFORMATpN Types Electric or Other Logs Run: CBL, GR/CCL, PEX, Quad Combo (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / type meairrmc ~.u~~~ur~~ame J1:~11e rviea~a no wart stop ~.n Kecewea ~ommenrs D C Lis 12738 Cement Evaluation 1 1900 6464 Case 9/21/2004 CEMENT BOND LOG ~g 12738 C ment Evaluation e BS 1 1900 6464 Case 9/21/2004 CEMENT BOND LOG C Lis i - 12737~Intluction/Resistivity 3500 6500 Open 9/21/2004 ARRAY INDUCTION, LITHO- DENSITY/COMPENSATED NEUTRON, GAMMA RAY "PLATFORM EXPRESS"` :, Vtog 12737 Induction/Resistivity Blu 2000 6500 Open 9!21/2004 ARRAY INDUCTION, LITHO- DENSITY/COMPENSATED NEUTRON, GAMMA RAY ED C Las // 12736 Mud Log 2 2010 6530 Open 9/21/2004 'PLATFORM EXPRESS" MD Mud Log and Drilling ~ Parameters ~g 12736 Mud Log 2 2010 6530 Open 9/21/2004 MD Mud Log HORIZON WELL LOGGING, INC. og 12736 Mud Log 2 BS 2010 6530 Open 9/21/2004 MD DRILLING PARAMETERS, HORIZON WELL LOGGING INC. ED C Las 12912 /Perforation 1 6100 6430 Case 12/7/2004 perforating record 3 3/8" HSD Gun og 12912 Perforation 5 Blu 1 6100 6430 Case 12/7/2004 perforating record 3 3/8" HSD Gun II DATA SUBMITTAL COMPLIANCE REPORT 6/21 /2010 Permit to Drill 2041630 Well NamelNo. SWANSON RIVER KGSF 7A Operator UNION OIL CO OF CALIFORNIA MD 6530 TVD 6530 Completion Date 9/2/2004 Completion Status GSTOR Current Status GSTOR Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y f1~V Chips Received? ~1- Analysis rrl~ Received? Daily History Received? ~~ N Formation Tops (..i'' N API No. 50-133-20538-01-00 UIC Y Comments: Compliance Reviewed By: Date: "V II i MEMORANDUM TO: Jim Regg ~ ~ P.I. Supervisor ~~ ~ ( fl((~~h FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, October 06, 2005 SUBJECT: Mechanical Integrity Tests UNION OII. CO OF CALIFORNIA KGSF 7A SWANSON RIVER KGSF 7A +~ +~.. Reviewed By: P.I. Suprv .Js~- Src: Inspector NON-CONFIDENTIAL Comm Well Name: SWANSON RIVER KGSF 7A API Well Number 50-133-20535-01-00 Inspector Name: Jeff Jones Insp Num: mitJJ050929130931 Permit Number: 204-163-0 Inspection Date: 9/27/2005 Rel Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ KGSF 7A IType Inj. CT I, TVD ~ 6077 ~ IA ~ 0 ~ 1600 ~ 1600 I 1600 I I P.T. 2041630 ~TypeTOSt ~ SPT ~ 'l'est psl ~ 1519.25 OA ~ 0 ~ 16 16 ~ 16 ~ ~ Interval 4YRTST P~ p 'j' g 2775 j 2800 2800 I 2800 j NOtes 1 well inspected, no exceptions noted. Thursday, October 06, 2005 Page 1 of 1 STATE OF ALASKA r ALAS LAND GAS CONSERVATION COMMI WELL COMPLETI OR RECOMPLETION R ORT AND`LOG TRUE Oil^ Gas ~ Plugged Abandoned 2oa4czs.~os GINJ ^ WINJ ^ WDSPL ^ No. of Completions Suspended^ WAG zoaac2s.~~o 2 Other 1b.WeIlClass: .-~ ~~ Development ^ Exploratory^ Service Q Stri~tgrAphac Test ^~ 2. Operator Name: Union Oil Company of California 5. Dat omp. Susp., or l Aband.: 9/.~. d 12. Permit to Drill Number: x'r i c r .' .2A4.981+- ~,pU 3. Address: PO Box 196247, Anchorage, AK 99519 6. Date Spudded: August 9, 2004 13. API Number: 50-133-20538-01 4a. Location of Well (Governmental Section): Surface: 1,999' FSL, 425' FEL, Sect. 28, T8N, R9W, S.M. 7. Date TD Reached: August 29, 2004 14. Well Name and Number: KGSF-07A Top of Productive Horizon: 2,000' FSL, 389' FEL, Sect. 28, T8N, R9W, S.M. 8. KB Elevation (ft): 174' 15. Field/Pool(s): Total Depth: 2,000' FSL, 389' FEL, Sect. 28, T8N, R9W, S.M. 9. Plug Back Depth(MD+TVD): 6,478'/6,478' Swanson River Field/Tyonek 64-5 4b. Location of Well (State Base Plane Coordinates): Surface: x- 347,290 y- 2,468,440 10. Total Depth (MD + TVD): 6,530'/6,530' 16. Property Designation: Swanson River Field TPI: x- 347,326 y- 2,468,441 Total Depth: x- 347,326 y- 2,468,441 11. Depth Where SSSV Set: n/a 17. Land Use Permit: A-028399 18. Directional Survey: Yes Q No ^ 19. Water Depth, if Offshore: n/a feet MSL 20. Thickness of Permafrost: n/a 21. Logs Run: CBL, GR/CCL, PEX, Quad Combo 22. CASING, LI NER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE AMOUNT FT TOP BOTTOM TOP BOTTOM CEMENTING RECORD PULLED 16" 68# K-55 0 41' 0 41' DRIVEN 9-5/8" 40# L-80 0 1950' 0 1,950' 12-1/4" 158 bbl lead, 27 bbl tail, cmt to surface 7" 26# L-80 0 6,522' 0 6,522' 8-1/2" 111 bbl lead, 29 bbl tail 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 6,379 to 6,387, 6 spf, 60-degree phasing. 4-1/2" 6,113' 6,077' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production: n/a Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate ~ Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity -API (corr): 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". none._ _ Y ~i*i1.iF ;: Form 10-407 Revised 12/2003 CONTINUED ON REVERSE / V 28• GEOLOGIC MARKER 29. FORMATION TESTS ' NAME TVD Include and briefly s rize test results. List intervals tested, and attach detailed supporting s necessary. If no tests were conducted, state "None". 53-OCT 5,579 5,283 none 55-5CT 5,868 5,571 D1CT 6,007 5,710 59-2S6 6,266 5,969 61-OCT 6,309 6,012 61-3ST 6,338 6,041 61-3S6 6,430 6,133 62-4CT 6,508 6,211 64-5ST 6,680 6,383 65-7ST 6,830 6,533 TD 6,846 6,550 30. List of Attachments: L~ir~it~onai Survey, 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steven S. Lambe 263-7637 Printed Name: Timothy C. Brandenburo Title: Drilling Manager Signature: Phone: 907-276-7600 Date: 1 /25/2004 ~ ~~ 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for 1 njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 8/25/04 From To Hours Remarks 0:00 0:30 0.5 TOOH F / 1630' T / 1540' 0:30 1:30 1.0 Circulate 196 Bbl no cement returns. 1:30 4:30 3.0 L/D 2 7/8 tubing. RD tubing tongs. Change elevators. 4:30 6:30 2.0 Cut drill line. 6:30 16:00 9.5 Test BOPE to 250/3,500 psi. Changed out 3-1/2" x 5" VBR to 4" pipe rams. Tested same to 250/3,500 psi. 16:00 17:00 1.0 RIH w/ 10 stds to displace mud. POOH w/same. Checked out casing @ +/-65' due to scarred DP. 17:00 21:30 4.5 PU BHI BHA #5. T/ 1224' Oriented MWD tool. Tested same. 21:30 23:00 1.5 TIH W/4" DP F/1224' T/ 1854' Kelly Up Wash to top of Cement @ slow pump rate. Top of Cement @ 2107' 23:00 23:30 0.5 Circ. and clean out hole, perform flow sensor check, set all parameters, 23:30 0:00 0.5 Drill (Slide) F/ 2107' - T / 2113' Kick off Note: BOPE test witness waived by Mr. Lou Grimaldi w/ AOGCC. Note: Received verbal approval from Mr. Winton Aubert w/AOGCC to proceed with drilling SRU KGSF #7A on 8/25/04 @ 16:15 hrs 8/26/04 From To Hours Remarks 0:00 3:30 3.5 Drill (slide total 34') F / 2113' - T / 2141' 3:30 9:30 6.0 Drill F / 2,141' - T / 2,900' 126' APIG per hr. with out kick off slide 759' 9:30 10:30 1.0 Rig # 2 Mud pump down Circ, & Reciprocate 10:30 17:30 7.0 Drill ahead F/ 2,900' - T / 3,401' at reduced pump rate of 475 GPM, Control drill while rig works on #2 pump. 71.57' APIG per hr. change all seats in #2 pump. 17:30 18:30 1.0 Drill Ahead F / 3,401' - T / 3,447' MWD lost Pulse @ 17:30 18:30 19:00 0.5 Work on getting MWD Pulse back 19:00 22:00 3.0 Drill ahead F / 3,447 - T / 3,715' 22:00 23:00 1.0 Drill ahead F / 3,715 - T / 3,758' #1 pump lost swab drill ahead @ slower rate 23:00 0:00 1.0 Drill ahead F / 3,715' - T / 3,811' Total APIG - 87.89' Per hr 19hrs Note: Received verbal approval from Mr. Tom Maunder w/AOGCC to drill to 4,300' without MWD operational. 8127104 From To Hours Remarks 0:00 3:30 3.5 Drill ahead F / 3,811' - T / 4,003' APIG 82' ft per hr. 22.5 hrs. 3:30 4:30 1.0 Drill ahead F / 4,003 ' - T / 4,050' #2 pump Down (SWAB) Drill ahead With #1 pump 4:30 6:00 1.5 Drill ahead F / 4,050' - T / 4,115'. Pumped sweep. 6:00 6:30 0.5 C&C mud. 6:30 13:30 7.0 POOH. 13:30 15:30 2.0 Changed out MWD tool and bit. Oriented MWD tool. 15:30 17:30 2.0 TIH w/same to 1950'. Tested MWD tool. 17:30 18:00 0.5 Serviced rig. 18:00 18:30 0.5 Repairing hydraulic leak on grabbers. 18:30 22:00 3.5 TIH from 1,950' to 4,115'. Stop and survey @ 3,800' 22:00 0:00 2.0 Drill Ahead from 4,115' - 4,254' APIG 69.5 Ft/hr 8/28/04 From To Hours Remarks 0:00 8:00 8.0 Drill ahead from 4,254' - 5145'. Bad swab in pump#2. APIG - 89' / HR (891' IN 10 HRS) 8:00 8:30 0.5 Drill ahead with pump #1 from 5,145' - 5,173'. 8:30 0:00 15.5 Drill ahead F/ 5,173' to T / 6,200' APIG 80.19' per hr. Total ft - 2,085' Total Hrs - 26hrs 8/29/04 KGSF-07A morning report summary, CONFIDENTAL: last revised 1/25/2005 Page 1 From To Hours Remart~ 0:00 6:30 6.5 Drilling Ahead F / 6,200' - T.D. @ 6,530' (Swab out #2 pump drill with one Pump F / 6,503' - T / 6,520') survey, drop carbide, dry run test, pump sweep, circ hole clean total APIG 77' per hr total ft 2,415' # 2 bit 6:30 9:30 3.0 POOH from 6,530' to 5,127'. 9:30 12:00 2.5 Back reamed from 5,127' to 4,770'. (Tight from 5,127' to 5,007'). 12:00 14:00 2.0 Pumped out of hole from 4,770' to 4,100'. 14:00 14:30 0.5 Pumped hi-visc sweep and C&C mud. 14:30 17:30 3.0 TIH from 4,100' to 6,530'. 17:30 18:30 1.0 Circulated walnut plug for flagging hole (5 bbl over calculated). C&C mud. Max Gas - 339 units. 18:30 0:00 5.5 POOH from 6,530' to 1,927'. (Tight spots from 4,068' to 3,808'). 8/30/04 From To Hours Remarks 0:00 3:30 3.5 POOH & LD BHA. Cleaned off rig floor. 3:30 5:00 1.5 RU Schlumberger EL. 5:00 7:30 2.5 Ran platform express log from 6,510' - 3,530'. 7:30 8:00 0.5 POOH & RD Schlumberger. 8:00 9:00 1.0 Pulled wear bushing. Made dummy run with Vetco Gray hanger and landing jt 9:00 11:30 2.5 RU Weatherford tools while waiting on Weatherford personnel. PU shoe & float joint. 11:30 12:00 0.5 Serviced rig 12:00 13:00 1.0 Changed out tongs due to improper heads. Changed out swivel on power pack. Held PJSM with Weatherford. 13:00 16:00 3.0 Ran 7", 26#, L-80 BTC casing to 1,950'. CBU @ shoe. 16:00 0:00 8.0 Ran 7" casing from 1,950' to 5,950'. Had to change out Weatherford tongs @ 3,487'. 8/31/04 From To Hours Remarks 0:00 2:30 2.5 Ran 7" casing from 5,950' to 6,512'. PU joint #158. Washed to 6,530'. Circ. CBU. L/D joint #158 2:30 6:00 3.5 M/U hanger and landing joint. Landed same &CBU. RU cement lines. Held PJSM. Flush lines with 3 BBL water PT lines to 4000 PSI. With rig pumped 25 BBL Mud push XL, shut down and batch up 12.8 PPG cement, Pump 111 BBL Lead Cement Slurry @ 12.8 PPG, followed by 29 BBL Tail Cement Slurry @ 15.8 PPG, Shut down, wash lines and drop plug. Pump 5 BBL mix water followed by 243 BBL mud pumped by rig, bumped plug at 05:47 HRS 6:00 7:00 1.0 Pressured up after bumping plug to 3500 PSI held for 30 minutes bled pressure off and checked floats had a total of 3 BBL return 7:00 8:00 1.0 RD Cement head, LD landing joint, clean floor. 8:00 9:30 1.5 Install 7" casing pack off and test to 5000 PSI held for 10 minutes, and install short wear ring 9:30 13:00 3.5 LD 5" HWDP. 13:00 13:30 0.5 RD Horizon crown sensor, Brk out drive sub XO from 7" landing joint 13:30 14:00 0.5 PU Bit, 7" casing scraper, Bit sub and XO 14:00 19:00 5.0 RIH with scraper assembly 19:00 19:30 0.5 Tag up at 6463' kelly up and rotate to 6475' Initially very hard had to set down 8-9K on bit and drilled off very slowly (1800-2100 Torque) broke through and drilled relatively easy from there. At or near BU from initial hard spot had rubber come across shaker screen. 19:30 21:00 1.5 CBU, finish cleaning pits, and flush lines 21:00 22:30 1.5 PJSM with all parties involved in fluid change over, Test casing to 3500 PSI-for 10 minutes with no pressure loss. Pump 75 BBL H2O followed by 50 BBL of dirt magnet chased by 150 NBBL of H2O followed by 50 BBL of KCL, chased by 65 BBL of H2O, taking returns to slop tank and centrifuge tanks. Water cleared up greatly after dirt magnet came back. KCL spotted at bottom of hole. 22:30 0:00 1.5 POOH LD DP KGSF-07A morning report summary, CONFIDENTAL: last revised 1/25/2005 Page 2 9/1 /04 • • From To Hours Remarks 0:00 5:00 5.0 POOH LD DP 5:00 6:00 1.0 Clean floor. Pull wear ring. 6:00 7:00 1.0 RU Schlumberger a-line 7:00 12:30 5.5 Run CBL, had to pull back out of hole at 5700' due to short in line. Rehead run back in well 6474' pressure casing to 1500 PSI and log out to 1925'. Top of cement appears to be at 2200', drop back down to 2400' and log back up to 1925' to verify TOC 12:30 13:00 0.5 RD SWS 13:00 14:30 1.5 Change out lower rams to 4.5", body test 250 PSI low and 3500 PSI high 14:30 15:30 1.0 RU WOTCO to run 4.5" tubing, hold PJSM prior to running pipe 15:30 18:30 3.0 RIH to 1611' had power pack problems 18:30 18:45 0.25 Change out power pack 18:45 21:00 2.25 RIH to 3609' 21:00 22:00 1.0 MU chemical injection line, hang control line sheave, and install chemical injection line. Pressure up line to 1000 PSI 22:00 0:00 2.0 RIH with 4.5" tubing, strapping 1/4" control line to tubing. RIH to 5113' BOP test waiver today at 16:38 by Winton Aubert with AOGCC. Test originally due today. Up 70M, DN 69M X-Nipple loaded with RHC plug 9/2/04 From To Hours Remarks 0:00 1:30 1.5 Continue to RIH 1:30 4:00 2.5 Install tubing hanger, and landing joint, MU chemical injection line, drain BOP, land hanger and verify correct setting in tubing spool. Close bag and pressure up to 700 PSI to verify hanger body seals intact, bleed off pressure. PU hanger 4', RD WOTCO tongs, MU Safety valve, head pin, and HP hose 4:00 5:00 1.0 Circulate inhibited packer fluid, and diesel for freeze protection 5:00 6:00 1.0 Drop bar wait 15 minutes, pump approx 7.5 bbl to pressure up. Ran pressure up to 2500 PSI and let sit for a couple of minutes, pressured up to 3500 PSI and waited and pump would not roll over with this much pressure, bled pressure back to 500 PSI and ran pump up to 4200 PSI and pop off blew. Repinned valve and proceeded to pressure up again to 4000 PSI shut in and after 1 minute sitting the off duty pump pop off blew (pump not isolated). Isolated pump and pressured up to 400 PSI and let sit for 10 minutes. Bled pressure off. Note all pumping was done with annulus valve open. (Packer setting) 6:00 7:30 1.5 Run 2" HP hose to cellar and connect to annulus. With TIW open pressure annulus to 2500 PSI and hold for 30 minutes, had approximately 20 PSI drop in pressure during test. Bled pressure off. 7:30 8:30 1.0 Break out TIW and head pin, lay down landing joint and install 4" Type H BPV 8:30 .13:30 5.0 Remove catch can and tarp, wash down BOP, open doors and removal all rams, NP bell nipple and flow line, pull rotary table 13:30 18:30 5.0 Clean and remove koomey lines, remove choke and kill lines, NP BOP 18:30 21:00 2.5 NU dry hole tree, Test 11" 5M tubing head adapter to 5000 PSI, Pull 4" Type H BPV and install 4" Type H TWC and attempt to test tree to 5000 PSI. Was not able to hold pressure, removed TWC and redressed, installed same and tested again to 5000 PSI held good. Removed TWC and installed BPV and secured well. Released rig at 21:00 HRS 21:00 23:00 2.0 Pumped packing in 16" x 9 5/8" void area of wellhead until solid, PT to 3000 PSI held for 30 minutes 23:00 0:00 1.0 Peak loading trailers and readying equipment for demob. 9/3-6/04 From To Hours Remarks 0:00 24:00 24.0 RD/MO 10/17/04 From To Hours Remarks KGSF-07A morning report summary, CONFIDENTAL: last revised 1/25/2005 Page 3 0:00 8:00 8.0 No acti~ • 8:00 9:00 1.0 Schlumberger on location, still pulling pit liner to prep., Spot vac truck with lease water for testing. 9:00 13:00 4.0 Spot unit, PJSM, RU, stab injector head & test hard lines. Prime G pump and fill coil. Test BOP 300# low and 3700# high (OK). 13:00 14:30 1.5 RIH with coil checking pick up weight every 1500', start cooling down N2 and start pumping 300 SCFM at 3000' RKB. Continue RIH and set down on bottom at 6471' coil measurement and pick up free, no extra weight. Reciprocate pipe above bottom and wait on N2 to make corner. 14:30 15:30 1.0 Circulate N2 while on bottom from 300 SCFM to 500 SCFM. Strap Johnson tank after returns are free of fluid and recovered 122 Bbl of fluid unloaded. 15:30 17:00 1.5 Shut in returns and pump 300 SCFM while POOH. 17:00 17:30 0.5 Close swab valve and both masters with 2600# of N2 on tubing. 17:30 21:30 4.0 Blow down and bleed down surface equipment. RD 10/24/04 From To Hours Remarks 0:00 8:00 8.0 Operation suspended 8:00 10:00 2.0 Schlumberger in field at 8:00 hrs, spot equipment 10:00 10:30 0.5 Change out tree top flange 10:30 11:45 1.25 Pick up lubricator, pre job safety and operations meeting, review Unocal perforating checklist. Arm 10' 3-3/8" 6spf HSD perforating gun with 8" loaded, stab lubricator, test same to 4200'. 11:45 12:45 1.0 RIH with perforating gun and CCL, noted fluid level at 5930', tie into Schlumberger CH CBL log dated 9-1-04, log on depth perforate 6375' to 6383' 12:45 15:00 2.25 POH, all shots fired, RD Schlumberger Well released to production KGSF-07A morning report summary, CONFIDENTAL: last revised 1/25/2005 Page 4 U~IOCAL® UNOCA~GSF#7 P8~S Yard, Swanson River Unit,Kenai Peninsula, Alaska(Imported) SURVEI~lIfSTING Page 1 Wellbore: KGSF#7A Wellpath: MWD<2060 - 6530> Date Printed: 25tilan-2005 BAKER • l~NNiMES INTEQ Wellbore Name ____ Created __ Last Revised ~____ KGSF#7A ____ 24-Auq-2004 ~ ____ 30-Auq-2004 Slot Name Grid Northin Grid Eastin Latitude Lon nude North Easf KGSF#7 2468439.6830 347290.4730 N60 45 13.6397 I W150 51 13.3883 203.49S 66.13E Installation Name Eastin Northin 'Coord S stem Name North Ali nment P&S Yard 347227.0000 2468644.0000 AK-4 on NORTH AMERICAN DATUM 1927 datum' True Field Name Eastin Northin Coord S stem Name North AI' nmenf Swanson River Unit 347751.9830 2471720.9650 AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and ND's are from Rig (Datum #2 173.9ft above mean sea level ) Vertical Section is from O.OON 0.00E on azimuth 0.00 degrees Bottom hole distance is 36.04 Feet on azimuth 88.04 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated UNbCAL® UNOCA~GSF#7 P8~S Yard, Swanson River Unit,Kenai Peninsula, Alaska(Imported) SURVE~STING Page 2 Wellbore: KGSF#7A Wellpath: MWD<2060 - 6530> Date Printed: 25-Jan-2005 INTEQ Well ath Grid Re ort MD[ftj Inc[degj Azi[deg] ND[ftj North[ftj East[ft] Dogleg Vertical deq/100ft Section ft Fasting Northing 0.00 0.00 0.00 0.00 O.OON i 0.00E 0.00 0.00 347290.47 2468439.68 50.00 0.15 232.67 50.00 0.04S 0.05W 0.30 -0.04 347290.42 2468439.64 100.00 0.15 270.31 100.00 0.08S 0.17W ' 0.19 -0.08 347290.30 2468439.61 150.00 0.12 169.16 150.00 0.13S _ 0.23W 0.42 0 13 347290.25 ~ 2468439.56 200.00 0.44 173.09 200.00 0.37S 0.19W 0.64 -0.37 347290.28 2468439.31 250.00 0.46 150.13 250.00 0.74S 0.07W ~I 0.36 ! -0.74 347290.39 2468438.95 300.00 I 0.55 153.59 300.00 1.13S 0.14 E 0.19 -1.13 347290.60 2468438.56 350.00 0.54 154.16 349.99 1.55S _ _ 0.35E 0.02 -1.55 347290.80 2468438.13 400.00 0.52 153.00 399.99 1.97S ~ 0.55E 0.05 -1.97 347291.00 2468437.71 ~~ 450.00 0.45 149.78 449.99 2.34S 0.76E 0.15 -2.34 347291.20 2468437.33 500.00 0.50 160.03 499.99 2.71 S I 0.93E 0.20 -2.71 347291.37 2468436.96 ~ 550.00 0.43 148.51 ~ 549.99 3.08S 1.10E 0.23 -3.08 347291.53 2468436.59 _, ' 600.00 0.40 132.15 ! 599.99 3.36S 1.33E 0.24 -3.36 347291.76 2468436.31 650.00 0.47 154.11 ! 649.98 3.66S 1.55E 0.36 -3.66 347291.97 2468436.01 I 700.00 i 0.37 151.95 699.98 3.98S 1.71E 0.20 -3.98 _____ 347292.13 2468435.68 750.00 ~ 0.41 ~ 146.77 - 749.98 4.28S 1.89E _ 0.11 -4.28 347292.30 2468435.38 800.00 ~ 0.30 131.63 799.98 4.51S 2.08E 0.29 -4.51 347292.50 2468435.14 850.00 0.30 141.98 849.98 4.70S 2.26E 0.11 -4.70 347292.67 2468434.95 900.00 0.18 180.50 899.98 4.88S 2.34E 0.39 _-4.88 347292.75 _ 2468434.77 950.00 0.25 146.36 949.98 5.05S 2.40E ~ 0.29 -5.05 347292.81 ~ 2468434.60 1000.00 0.26 163.72 999.98 5.25S 2.49E 0.16 -5.25 347292.90 2468434.40 1050.00 0.24 166.33 1049.98 5.46S 2.55E 0.05 ! -5.46 347292.95 2468434.19 1100.00 0.31 160.61 1099.98 5.69S 2.62E I 0.15 -5.69 347293.02 2468433.96 1150.00 0.26 155.71 1149.98 5.92S 2.71E 0.11 -5.92 ___347293.11 2468433.72 _ 1200.00 0.32 130.40 1199.98 6.12S ~ 2.86E _ 0.28 ~ -6.12 347293.26 2468433.53 1250.00 0.20 151.55 _ 1249.97 6.29S 3.01E 0.30 -6.29 347293.40 2468433.36 1300.00 0.18 ! __ 180.61 1299.97 6.44S 3.05E 0.19 -6.44 347293,44 2468433.20 1350.00 ~ 0.16 139.66 ~ 1349.97 6.57S 3.10E 0.24 -6.57 347293.48 2468433.07 1400.00 0.34 ! 168.73 ( 1399.97 6.77S 3.17E 0.43 -6.77 347293.55 2468432.87 _ 14 50.00 I 0.28 + 159.78 ~ 1449.97 7.03S 3.24E 0.15 -7.03 347293.62 I 2468432.61 ~ 1500.00 ~ 0.28 _ 142.14 _ 1499.97 7.24S _ 3.36E 0.17 -7.24 __347293.74 2468432.40 1550.00 0.25 113.02 1549.97 7.38S 3.53E 0.27 -7.38 347293.91 2468432.26 1600.00 0.32 118.44 1599.97 7.49S 3.76E I . 0.15 i -7.49 347294.13 2468432.14 1650.00 0.23 141.25 1649.97 7.64S ! 3.94E 0.28 ! -7.64 347294.32 2468432.00 1700.00 0.24 142.35 1699.97 7.80S 4.07E 0.02 -7.80 347294.44 2468431.83 1750.00 0.45 110.64 1749.97 7.95S 4.32E 0.55 -7.95 347294.69 2468431.68 1800.00 0.39 154.38 ' 1799.97 8.17S 4.58E 0.64 -8.17 _ 347294.94_ 2468431.45 1850.00 ! 0.24 131.35 i 1849.97 8.39S 4.73E 0.39 -8.39 __ 347295.09 ! 2468431.23 1900.00 0.19 i 73.81 ' 1899.97,_ 8.44S 4.88E ~ 0.42 -8.44 347295.25 2468431.18 1931.00 ~ 0.50 68.84 1930.97 8.38S 5.06E . 1.00 -8.38 347295.42 ~ 2468431.24 2061.00 0.35 52.91 2060.96 7.93S i 5.91E ' 0.15 -7.93 ___ 347296.28 _ 2468431.67 2127.00 0.35 13.15 2126.96 7.62S 6.11E _. 0.36 ; -7.62 347296.49 2468431.99 2189.00 0.53 154.83 ._ 2188.96 7.69S 6.28E 1.34 -7.69 347296.65 2468431.91 2315.00 0.70 160.10 __ ~ 2314.95 8.94S 6.79E 0.14 -8.94 347297.14 2468430.65 _ 2440.00 0.62 ! 186.12 ; 2439.95 10.33S 6.98E 0.25 -10.33 347297.31 ! 2468429.26 2565.00 ( 0.44 ~ 174.87 I 2564.94 11.48S 6.95E 0.17 -11.48 347297.27 i 2468428.11 __ 2692.00 0.53 152.72 2691.94 12.49S 7.26E I 0.16 ! -12.49 347297.57 2468427.10 2819.00 0.53 168.19 2818.93 13.59S i 7.65E 0.11 -13.59 347297.94 2468426.00 3263.00 0.44 170.65 3262.92 17.28S 8.35E 0.02 -17.28 _ 347298.59 2468422.30 3760.00 0.26 _ 164.35 3759.91 20.25S 8.96E 0.04 -20.25 347299.17 2468419.32 4077.00 0.18 126.35 ~ 4076.90 21.24S 9.55E 0.05 -21.24 347299.75 2468418.33 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and ND's are from Rig (Datum #2 173.9ft above mean sea level ) Vertical Section is from O.OON 0.00E on azimuth 0.00 degrees Bottom hole distance is 36.04 Feet on azimuth 88.04 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated UNOCAL® UNOCA~GSF#7 PAS Yard, Swanson River Unit,Kenai Peninsula, Alaska(Imported) SURVE~STING Page 3 Wellbore: KGSF#7A Wellpath: MWD<2060 - 6530> Date Printed: 25tilan-2005 6A1(~E~R ~ fRlfil~5 INTEQ Well ath Grid Re ort MD[ft] Inc[deg] Azi[deg] 1VD(ft] North[ft] East[ft] Dogleg de~00ft Vertical Section ft Easting -- Northing 4328.00 0.44 ':, 66.94 4327.90 21.09S 10.76E 0.15 ~ -21.09 347300.96 2468418.45 4575.00 0.62 ~ 66.94 i 4574.89 20.20S ~ 12.86E ' 0.07 ~ -20.20 347303.07 2468419.32 4823.00 0.79 ~ 45.85 ~ 4822.87 18.48S 15.32E 0.12 -18.48 347305.55 2468421.01 5079.00 1.05 ~ 51.12 I 5078.84 15.78S ~i 18.41E 0.11 -15.78 347308.68 2468423.67 5331.00 1.14 1 49.71 ' 5330.79 12.71 S 22.13E ~ 0.04 -12.71 347312.43 2468426.69 5582.00 0.88 53.58 5581.75 9.95S ~ 25.58E ~ 0.11 -9.95. 347315.92 2468429.40 5833.00 0.88 ~ 46.90 5832.72 7.49S 28.54E ' 0.04 -7.49 347318.91 246843L82 _ 6083.00 0.97 ~ 48.66 6082.69 4.78S 31.53E I 0.04 ~ -4.78 347321.94 2468434.49 6336.00 0.97 ! 31.78 6335.65 1.54S 34.27E ' 0.11 -1.54 347324.71 2468437.69 6480.00 0.97 32.49 6479.63 0.52N ~ 35.56E 0.01 0.52 347326.04 2468439.74 ~_ 6530.00 0.97 32.49 6529.63 1.23N 36.02E 0_00 1.23 _ 347326.50 2468440.45 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and ND's are from Rig (Datum #2 173.9ft above mean sea level ) Vertical Section is from O.OON 0.00E on azimuth 0.00 degrees Bottom hole distance is 36.04 Feet on azimuth 88.04 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Uil10tA1.® UNOCA~GSF#7 PAS Yard, Swanson River Unit,Kenai Peninsula, Alaska(Imported) SURVE~STING Page 4 Wellbore: KGSF#7A Wellpath: MWD<2060 - 6530> Date Printed: 25-Jan-2005 ~~~ INTEQ Comments MD ft ND ft North~ft East ft .Comment _ 6530.00 _x___6529.63 1.23N 36.02E Protection to TD Hole Sections Diameter in Start MD ft Start ND ft Start North Start End Eas ft MD ft End N ft End Start North ft Eas ft Wellbore 121/4 0.00 0.00 O.OON 0.00E i 2000.00 1999.96 8.15S ! 5.56E KGSF#7 81/2 2000.00.._ 1999.96 8.15S 5.56E 6846.00 6552.58 5.75N i 38.89E KGSF#7 Casin s Name Top Top MD ft ND ft Top North ft Top Shoe Eas ft MD ft .Shoe ND ft Shoe North ft Shoe East ft Wellbore 16.OOOin Casin 0.00 ! 0.00 O.OON 0.00E 77.00 77.00 0.07S 0.11 W KGSF#7 9 5/8in Casin 0.00 i 0.00 O.OON 0.00E 1984.00 1983.97 8.21S ~ 5.46E KGSF#7 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and ND's are from Rig (Datum #2 173.9ft above mean sea level ) Vertical Section is from O.OON 0.00E on azimuth 0.00 degrees Bottom hole distance is 36.04 Feet on azimuth 88.04 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated • V N 0 CA ~ 76 Swanson River Field KGSF #7A Final Completion Schematic Jewelry Detail 1. 41' 16" Drive Shoe 2. 1,950' 9-5/8" Surface Casing 3. 6,522' 7" Production Casing 4. 2,497' Chemical Injection Mandrell 5. 6,113' 4-1 /2" Tubing 6. 6,077' Baker Primier Packer 7" - 26# 7. 6,097' BX Nipple 8. 6,112' W LEG Bit Sizes: 12-1/4", and 8-1/2" 9-5/8" Cemented to surface -Existing 7" Cemented to 1950' CASING DETAIL SIZE WT GRADE CONN TOP BOTTOM 18 68 K-55 BTC 0' 41' 9-5/8" 40 L-80 BTC 0' 1,950' 7" 26 L-80 BTC 0' 6,522' TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 4-1/2" 12.6 L-80 IBTC (AB Mod) 0' 6,113' Perforations (Tyonek 64-5 Sand) Date TOP BOTTOM SPF Deg 10/24/04 6,379' 6,387' 6 60 deg psg Straight Hole: MD =TVD TD = 6,530' MD / 6,530' TVD PBTD = 6,478' TVD / 6,478' TVD KGSF #7A FINAL REVISED: 12/15/04 DRAWN BY: SAM RKB to GL = 24.74' 716104 • From To Hours Remarks 0:00 0:00 24.0 Peak moved guard shack, heater, and misc. off pad are over week end. Shipped pipe and shoe to Peak to weld on shoe and prep pipe, 1 joint 18" thin wall cut to 15' for mouse. Pipe and cellar will be shipped to SRF Wednesday a.m. Leveled pad. 7/7104 From To Hours Remarks 0:00 0:00 24.0 Finished hauling gravel and leveling pad. Excavated and set cellar. Received conductor, landing plate and ladder. 7/8104 From To Hours Remarks 0:00 0:00 24.0 Excavate and set 18" mouse hole, level pad. 7/12/04 From To Hours Remarks 0:00 0:00 24.0 Toloff mobilized crane and hammer and rigged up over KGSF # 7. 7113/04 From To Hours Remarks 0:00 0:00 24.0 Toloff picked up and drove 16" conductor with a D12 hammer to 41' stopped at 280 blows. Pumped water from cellar. Install landing plate. 7114104 From To Hours Remarks 0:00 0:00 24.0 Finished hauling sand and gravel and leveled pad. Cemented in cellar. Installed a cap for mouse hole with tabs. Clean up location, set boards over cellar and barricades. 813/04 From To Hours Remarks 0:00 0:00 24.0 Clean and grade pad at injection well, grade pad at KGSF-0 7 location. 8/7104 From To Hours Remarks 0:00 0:00 24.0 Continue to RU, utility module and rig package stacked, derrick sooped up, hooking up hydraulics, fuelled day tank. Installed and tested Vetco starting head test to 500 PSI held for 30 minutes. Had welder modify bell nipple to fit. Wired up camps after arriving. 8/8/04 From To Hours Remarks 0:00 6:00 6.0 RU, pull electric lines and hooking up electric components. 6:00 18:00 12.0 Spot Baroid shack Peak connex and change room wire in same. Continue to RU, hook up and test choke lines, repair TD grabber. 18:00 0:00 6.0 Rig Accepted at 18:00 HRS, mix mud, change liners in pump 1 to 5.5" from 4.5", gather BHA equipment 8/9104 From To Hours Remarks 0:00 2:00 2.0 Continue to mix mud and change liners to 5.5" 2:00 6:00 4.0 Strap BHA components and PU 6:00 14:00 8.0 Spud well at 33' very ratty going through lots of gravel for first 200'. Continue to drill with operation smoothing out, Drill to 478' 14:00 15:00 1.0 Shut down due to electrical problems with UPS 15:00 0:00 9.0 Rotary drill 478' to 1460' 8/10/04 From To Hours Remarks 0:00 4:30 4.5 Rotary drill 1460' to 2000' TD 4:30 5:30 1.0 CBU, Pump high visc sweep with nut plug, flag back at 291 BBL, calculated annular volume of 251 BBL (40 BBL washout.) Pump dry job KGSF-07 morning report summary, AFE 162678, CONFIDENTAL: last revised 12/15/2004 Page 1 5:30 6:00 0.5 POOH~15K over pull at 1905', Pump out of hole 6:00 9:30 3.5 Pump out of hole to 330' top of 5" HWDP 9:30 10:00 0.5 Circulate and condition mud pump several BU until shakers cleared 10:00 11:30 1.5 TIH to 2000' 11:30 12:00 0.5 Pump hi-visc sweep 12:00 16:00 4.0 Pump out of hole from 2000' to 330' top of 5" HWDP 16:00 20:30 4.5 Hold PJSM discuss safe handling of 8" collars and stabilizers and effectively pumping out of hole. Pump out of hole laying down 5" HWDP, 8" DC, XO, Stabs, Pony collar, bit sub and bit 20:30 22:00 1.5 RU to run 9 5/8" casing 22:00 0:00 2.0 Run guide shoe joint along with float collar joint and fill and test float equipment, continue to run 9 5/8" casing. 8/11 /04 From To Hours Remarks 0:00 4:00 4.0 Run 9 5/8" casing to 1950 + /-" tagged up 4:00 6:00 2.0 Worked pipe with varying pump rates. Was able to bury joint, with a 4' Stick up 6:00 6:30 0.5 C&C mud 6:30 9:00 2.5 PU last joint of casing was able to work down to were we had 10' above rotary 9:00 12:00 3.0 C&C mud, RD WOTCO tongs, RU Cement manifold 12:00 13:00 1.0 RD circulating head and RU cement head 13:00 15:00 2.0 Pumped 3 BBL water at 3 BPM rate, Pressure tested lines to 4000 PSI, pumped 20 BBL mud push at 5 BPM rate. Batch up to 12.8 PPG and pump 158 Bbl lead cement slurry at 12.8 PPG, followed by 27 BBL tail at 15.8 PPG. Shut down and drop plug, Pumped 5 Bbl mix water and watched tattle tale move indicating plug release. Using rig pump chased plug with 143.6 BBL 9.1 PPG WBM, bumped plug within 10 strokes of calculated number. Pressured up to 3500 PSI and charted for 30 minutes. Cement returns to surface. 15:00 15:30 0.5 Hold 3500 psi on plug for 30 minutes, bled off to check floats. Had 2 BBL bleed back 15:30 16:30 1.0 RD cement head, spiders and cement equipment 16:30 17:30 1.0 Remove flow line and bell nipple riser 17:30 19:00 1.5 Set C-22 slips with 60K and rough cut 9 5/8" casing 19:00 20:30 1.5 Remove rotary table bail extensions and riser pipe, do final cut on casing 20:30 0:00 3.5 Set (Vetco) well head and NU same, with plastic packing, and attempt to test. 8/12/04 From To Hours Remarks 0:00 1:30 1.5 Pressure casing to 4500 PSI to test secondary seal of wellhead 1:30 2:00 0.5 RD Vetco Gray test equipment, Change liners in MP #1 back to 4.5". Change out dampener 2:00 17:00 15.0 NU BOP, hook up koomey hoses, connect choke and kill lines, function test, install catch can, bell nipple and flow line. 17:00 17:30 0.5 Install rotary table 17:30 18:30 1.0 Pick up test equipment and make up 18:30 0:00 5.5 Test BOP 8/13/04 From To Hours Remarks 0:00 .3:00 3.0 Test BOPs 3:00 5:00 2.0 RU Scientific portable E-line & Run gyro survey. 5:00 13:00 8.0 PU BHA and RIH 13:00 15:00 2.0 Tag cement wiper plug at 1940', checked up weight of 60M and down weight of 60M. Drill shoe track and rat hole along with 15' of new hole to 2017'. 15:00 16:00 1.0 CBU. 16:00 17:00 1.0 Pertorm LOT, had a 16.2 EMW 17:00 0:00 7.0 Directional drill from 2017, to 2665' Gyro survey to 1931' in 9 5/8" casing 1930' MD, .50 INC, 68.84 AZ, 1930.97 TVD Survey: MD 2691', TVD 2676 INC 20.80 Azimuth 14.64 8/14104 KGSF-07 morning report summary, AFE 162678, CONFIDENTAL: last revised 12/15/2004 Page 2 ~ From To Hours Remar 0:00 6:00 6.0 Drilled F/ 2665' to 3113', Swept at 3000' 6:00 12:00 6.0 Drilled F/ 3113' to 3746', Swept at 3400' UPWT 84K, DNWT 76K, RTWT 84K 12:00 17:30 5.5 Drilled F/ 3746' to 4272', Swept at 4200' 17:30 21:30 4.0 Electric #2 mud pump went down. Held PJSM, performed lock out tag out on pump, and energy isolation on valves. Replaced seat, valves, and new spring retainer. Remove locks from lock out tag out. Bring pumps back on line. 21:30 0:00 2.5 Drill 30' kelly down, make connection. Attempt to pump survey with no success. Shut down pumps for 3 min, bring pump up to 650 GPM, still no signal. Check wires on MWD unit and rig floor, Pump sweep, and pump 40 bbl of water. Attempt to pump survey with no success. Baker (MWD) seems to think that the turbine in not turning. 8/15104 From To Hours Remarks 0:00 3:30 3.5 POOH from 4095' tight at 2990', pumped and wiped clean continue to POOH with 4" pipe 3:30 7:00 3.5 POOH with 4" and 5" HWDP connection (very tight), 7:00 10:00 3.0 Stand back flex collars, drain motor, inspect bit, Change out MWD and orientate tool 10:00 11:30 1.5 RIH to 2000' 11:30 12:00 0.5 Service rig 12:00 15:00 3.0 RIH to 4293' set down KU and pump, could not wash rotated down to 4348' 15:00 0:00 9.0 Pump sweep and start to directional drill from 4348' to 4630' TRH 1.9 ROP 87.4 TSH 4 ROP 4.0 TDH 5.9 TROP 47.6 Off bottom circulation Hrs 3.7 Com Circ Time 9.6 Up WT 95M down WT 74M RT WT 84M, Torque on BTM 4-6 off BTM 4-6 8/16/04 From To Hours Remarks 0:00 19:00 19.0 Directional drill to 5430." 19:00 0:00 5.0 Rotary drill to 5850' ART 7.5 926' ROP 123.5 AST 15.3 575' ROP 37.6 ACT 1.8 8117/04 From To Hours Remarks 0:00 2:00 2.0 Rotary drill to 6073' lost swab in #1 pump. 2:00 5:00 3.0 Swab repaired and drilling from 6073' to 6200' 5:00 0:00 19.0 Directional drilled from 6,200'-6,810. APIG-59.0'/hr ART - 16.9 hrs AST - 0 hrs Survey - 6,720' MD, 1.99 degrees @ 6,426.66' TVD with 25.75 Azimuth 8/18/04 From To Hours Remarks 0:00 0:30 0.5 Drilled from 6,810' to 6,846' MD. Took influx @ 6,846" / 6,551' TVD. 14 bbl pit gain with 175 psi SICP and 0 psi SIDPP. 0:30 3:30 3.0 Circulating kick using step 1 of drillers method with 9.4 ppg mud. SD pump SICP-370, SIDPP-330. 3:30 5:30 2.0 Bled 2 bbl to trip tank off annulus. DP-0 psi, csg-75 in 50 minutes. 5:30 7:00 1.5 Bled 4 bbl to trip tank from annulus. DP - 0 psi, casing - 20 psi. Monitored well for 1 hr. DP - 130 psi, casing - 264 psi. 7:00 10:00 3.0 Circulated BU using step 1 of drillers method. SD pumps/closed choke. SIDPP - 360 psi, SICP - 365 psi. KGSF-07 morning report summary, AFE 162678, CONFIDENTAL: last revised 12/15/2004 Page 3 10:00 11:30 1.5 SIDPP~ psi, SICP - 321 psi. Bled 1 bbl from anr~ to trip tank. DP - 90 psi, Casing - 91 psi. Monitored 10 minutes. SIDP - 90 psi, SICP - 100 psi. 11:30 17:00 5.5 Transferred mud and weighted up active pits to 9.8 ppg. Held PJSM on circulating killing procedure. 17:00 21:00 4.0 Circulated KWM using step 2 of drillers method. SD pumps/closed choke. SIDPP - 0 psi, SICP - 0 psi. Monitored well shut-in for 30 minutes. Pressures remained 0 psi. 21:00 23:00 2.0 Opened hydril. Monitored well while transferring mud to active pits. Well giving large gas bubbles. No flow. 23:00 0:00 1.0 Circulated 2 BU. Recovered large coal cuttings and sand. Max gas - 475 units. SD pumps. Monitored well. Well slightly flowing. Started pumps. Get slow pump rates. Continued circulating additional 50 bbl. SD pumps. Fluid level falling slowly. No flow. Survey - 6,800' MD, 2.08 degrees @ 6,506' TVD with 27.18 azimuth 8119104 From To Hours Remarks 0:00 0:30 0.5 Monitored well for 30 minutes. Fluid level dropped 1 ft. in stack. 0:30 3:30 3.0 CBU and pumped hi-visc sweep. Lost 7 bbl mud during BU. High gas - 150 units. SD pumps. Monitored well. Well static. 3:30 20:00 16.5 Pumped out of hole making short trip to 2,800'. Tight spots resulted in back-reaming. 20:00 20:30 0.5 CBU and pumped hi-visc sweep. 20:30 0:00 3.5 RIH following short trip @ 6,025' 8/20104 From To Hours Remarks 0:00 3:00 3.0 Tagged coal @ 6,025'. Reamed through. CIH to bottom having to ream tight spots @ 6,030', 6,318' and 6,522' 3:00 5:00 2.0 Tagged TD @ 6,846'. Pumped hi-visc sweep with walnut plug and gauged hole (485 bbl). Total volume = 452 bbl. C&C mud. 5:00 7:30 2.5 Back reamed from 6,846'-5,950'. 7:30 8:00 0.5 C&C mud. Changed swab on #2 pump. 8:00 9:30 1.5 RIH from 5,950' to 6,846'. Spot reamed in tight spots @ 6,030', 6,318' and 6,522'. PU wt - 120K, SO wt - 92K 9:30 10:30 1.0 C&C mud. Pumped sweep 10:30 20:00 9.5 Pumped out of hole from 6,846' to 6,074'. Pumped slug. Pulled out of hole and racked back BHA. 20:00 21:30 1.5 RU Schlumberger Electric line. 21:30 23:30 2.0 RIH with Quad Combo. Unable to get below 6,020' with 4-1/2" max OD. POOH. 23:30 0:00 0.5 Removed density tool and centralizers. Max OD 3-5/8". Note: Received extension for BOP test from AOGCC on 8/20/04. 8/21/04 From To Hours Remarks 0:00 2:00 2.0 RIH with new tool string. Unable to get below 6,020'. 2:00 4:30 2.5 Logged from 6,020 to surface (GR). RD EL 4:30 6:00 1.5 LD Baker BHA. 6:00 6:30 0.5 Pull wear bushing and MU test jt. 6:30 19:30 13.0 Tested BOPE to 250/3,500 psi for 4", 4-1/2" & 7". 19:30 20:30 1.0 LD test equipment. Installed wear bushing 20:30 23:00 2.5 Tested flow, volume and G/L sensors. 23:00 0:00 1.0 Held PJSM with Reeves on shuttle system. Picked up 3-1/2" shuttle system. 8/22/04 From To Hours Remarks 0:00 2:30 2.5 MU Reeves logging tools and tested same. Broke circ and logged rates. 2:30 10:00 7.5 RIH w/same on 4" DP drifting same. TIH to 5,900'. CBU. Max gas - 149 units. 10:00 11:30 1.5 CIH and tagged @ 6,027' Circ & rotate, Worked through. TIH to 6,831'. PU wt - 110K, SO - 84K. 11:30 12:30 1.0 Start circulating, noticed flow increase on flow meter. Check well -flowing at 17%. Shut in well. DP - 40 psi, Casing - 12 psi. Monitored pressures - DP - 100 psi, casing -95 psi. KGSF-07 morning report summary, AFE 162678, CONFIDENTAL: last revised 12/15/2004 Page 4 12:30 16:30 4.0 Bled 1/~ through choke pressures went to 0 psi. ~ned well and circulated. Max gas - 2,500 units. Continue to circulate out gas with no success. Increased mud weight to 10.2 and circulated same. Well static. 16:30 17:00 0.5 POOH to 6,746'. Dropped dart and pumped same down. Sheared and dropped tools into logging position. 17:00 0:00 7.0 POOH and logged with triple combo from 6,834' to 5,600' at 2 minutes per stand. Battery life over for logging tools. Pumped dry job and POOH. LD 3-1/2" shuttle system and logging tools. 8123/04 From To Hours Remarks 0:00 3:00 3.0 PU BHA #4 for cleanout run. RIH to 1960'. 3:00 3:30 0.5 Serviced rig. 3:30 16:30 13.0 RIH w/BHA #4 to 6,846'. Washed & reamed tight spots @ 4,377', 4,420', 4,530', 6,113', 6,225', 6,476' & 6,676'. 16:30 17:30 1.0 C&C mud. Max gas - 127 units. 17:30 0:00 6.5 Pumped out of hole to 6,608'. Pumped dry job. POOH. Tight spots @ 5,763', 5,608', 5,634' & 4,304' Note: Verbal approval from Porhola w/BLM to proceed with P&A and sidetrack. 8/24/04 From To Hours Remarks 0:00 1:30 1.5 Continue POOH & LD BHA #4. 1:30 2:30 1.0 RU Weatherford tongs & held PJSM. 2:30 5:30 3.0 PU & RIH w/2-7/8" stinger. 5:30 6:30 1.0 RIH w/ 551' 4" HWDP. Broke circulation. 6:30 10:00 3.5 RIH from 1,984' to 6,846'. PU wt - 90K, SO wt - 78K. 10:00 11:30 1.5 C&C mud. Held PJSM with Schlumberger for cement job. 11:30 12:30 1.0 RU cement equipment. Tested same to 2,000 psi. 12:30 13:30 1.0 Pumped 70.5 bbl 15.8 ppg cement, displaced with 60 bbl 10.2 ppg mud balancing a 896' cement plug in 8-1/2" hole from 6,846' to 5,950'. Cement in place @ 1300 hrs 13:30 15:30 2.0 POOH to 5,900'. CBU w/ 2,400 psi @ 430 gpm. 15:30 17:30 2.0 Pumped 75 bbl 15.8 ppg cement, displaced with 48 bbl 10.2 ppg mud balancing a 950' cement plug from 5,900' to 4,950'. Cement in place @ 1700 hrs. 17:30 20:00 2.5 POOH to 4,500'. Reverse circulated 2 DP volumes with 300 psi pump pressure. 20:00 21:30 1.5 POOH to 2,500'. CBU w/ 1,230 psi @ 430 gpm. 21:30 23:00 1.5 Pumped 43 bbl 17.0 ppg cement. Had problems with Schlumberger pump. Aborted cement job. Pulled 2 stds. Pumped 11 bbl 10.2 ppg mud down DP. Estimated TOC - 1,908'. 23:00 0:00 1.0 POOH @ 1500'. 8/25/04 From To Hours Remarks 0:00 0:30 0.5 TOOH F / 1630' T / 1540' 0:30 1:30 1.0 Circulate 196 Bbl no cement returns. 1:30 4:30 3.0 L/D 2 7/8 tubing. RD tubing tongs. Change elevators. 4:30 6:30 2.0 Cut drill line. 6:30 16:00 9.5 Test BOPE to 250/3,500 psi. Changed out 3-1/2" x 5" VBR to 4" pipe rams. Tested same to 250/3,500 psi. 16:00 17:00 1.0 RIH w/ 10 stds to displace mud. POOH w/same. Checked out casing @ +/-65' due to scarred DP. 17:00 21:30 4.5 PU BHI BHA #5. T/ 1224' Oriented MWD tool. Tested same. 21:30 23:00 1.5 TIH W/4" DP F/1224' T/ 1854' Kelly Up Wash to top of Cement @ slow pump rate. Top of Cement @ 2107' 23:00 23:30 0.5 Circ. and clean out hole, perform flow sensor check, set all parameters, 23:30 0:00 0.5 Drill (Slide) F/ 2107' - T / 2113' Kick off Note: BOPE test witness waived by Mr. Lou Grimaldi w/ AOGCC. Note: Received verbal approval from Mr. Winton Aubert w/AOGCC to proceed with drilling SRU KGSF #7A on 8/25/04 @ 16:15 hrs KGSF-07 morning report summary, AFE 162678, CONFIDENTAL: last revised 12/15/2004 Page 5 ~ • 8126/04 From To Hours Remarks 0:00 3:30 3.5 Drill (slide total 34') F / 2113' - T / 2141' 3:30 9:30 6.0 Drill F / 2,141' - T / 2,900' 126' APIG per hr. with out kick off slide 759' 9:30 10:30 1.0 Rig # 2 Mud pump down Circ, & Reciprocate 10:30 17:30 7.0 Drill ahead F/ 2,900' - T / 3,401' at reduced pump rate of 475 GPM, Control drill while rig works on #2 pump. 71.57' APIG per hr. change all seats in #2 pump. 17:30 18:30 1.0 Drill Ahead F / 3,401' - T / 3,447' MWD lost Pulse @ 17:30 18:30 19:00 0.5 Work on getting MWD Pulse back 19:00 22:00 3.0 Drill ahead F / 3,447 - T / 3,715' 22:00 23:00 1.0 Drill ahead F / 3,715 - T / 3,758' #1 pump lost swab drill ahead @ slower rate 23:00 0:00 1.0 Drill ahead F / 3,715' - T / 3,811' Total APIG - 87.89' Per hr 19hrs Note: Received verbal approval from Mr. Tom Maunder w/AOGCC to drill to 4,300' without MWD operational. 8127/04 From To Hours Remarks 0:00 3:30 3.5 Drill ahead F / 3,811' - T / 4,003' APIG 82' ft per hr. 22.5 hrs. 3:30 4:30 1.0 Drill ahead F / 4,003 ' - T / 4,050' #2 pump Down (SWAB) Drill ahead With #1 pump 4:30 6:00 1.5 Drill ahead F / 4,050' - T / 4,115'. Pumped sweep. 6:00 6:30 0.5 C&C mud. 6:30 13:30 7.0 POOH. 13:30 15:30 2.0 Changed out MWD tool and bit. Oriented MWD tool. 15:30 17:30 2.0 TIH w/same to 1950'. Tested MWD tool. 17:30 18:00 0.5 Serviced rig. 18:00 18:30 0.5 Repairing hydraulic leak on grabbers. 18:30 22:00 3.5 TIH from 1,950' to 4,115'. Stop and survey @ 3,800' 22:00 0:00 2.0 Drill Ahead from 4,115' - 4,254' APIG 69.5 Ft/hr 8/28104 From To Hours Remarks 0:00 8:00 8.0 Drill ahead from 4,254' - 5145'. Bad swab in .pump #2. APIG - 89' / HR (891' IN 10 HRS) 8:00 8:30 0.5 Drill ahead with pump #1 from 5,145' - 5,173'. 8:30 0:00 15.5 Drill ahead F/ 5,173' to T / 6,200' APIG 80.19' per hr. Total ft - 2,085' Total Hrs - 26hrs 8129/04 From To Hours Remarks 0:00 6:30 6.5 Drilling Ahead F / 6,200' - T.D. @ 6,530' (Swab out #2 pump drill with one Pump F / 6,503' - T / 6,520') survey, drop carbide, dry run test, pump sweep, circ hole clean total APIG 77' per hr total ft 2,415' # 2 bit 6:30 9:30 3.0 POOH from 6,530' to 5,127'. 9:30 12:00 2.5 Back reamed from 5,127' to 4,770'. (Tight from 5,127' to 5,007'). 12:00 14:00 2.0 Pumped out of hole from 4,770' to 4,100'. 14:00 14:30 0.5 Pumped hi-vise sweep and C&C mud. 14:30 17:30 3.0 TIH from 4,100' to 6,530'. 17:30 18:30 1.0 Circulated walnut plug for flagging hole (5 bbl over calculated). C&C mud. Max Gas - 339 units. 18:30 0:00 5.5 POOH from 6,530' to 1,927'. (Tight spots from 4,068' to 3,808'). 8/30/04 From To Hours Remarks 0:00 3:30 3.5 POOH & LD BHA. Cleaned off rig floor. 3:30 5:00 1.5 RU Schlumberger EL. 5:00 7:30 2.5 Ran platform express log from 6,510' - 3,530'. 7:30 8:00 0.5 POOH & RD Schlumberger. 8:00 9:00 1.0 Pulled wear bushing. Made dummy run with Vetco Gray hanger and landing jt KGSF-07 morning report summary, AFE 162678, CONFIDENTAL: last revised 12/15/2004 Page 6 9:00 11:30 2.5 RU We~rford tools while waiting on Weatherford ~onnel. PU shoe & float joint 11:30 12:00 0.5 Serviced rig 12:00 13:00 1.0 Changed out tongs due to improper heads. Changed out swivel on power pack. Held PJSM with Weatherford. 13:00 16:00 3.0 Ran 7", 26#, L-80 BTC casing to 1,950'. CBU @ shoe. 16:00 0:00 8.0 Ran 7" casing from 1,950' to 5,950'. Had to change out Weatherford tongs @ 3,487'. 8/31 /04 From To Hours Remarks 0:00 2:30 2.5 Ran 7" casing from 5,950' to 6,512'. PU joint #158. Washed to 6,530'. Circ. CBU. L/D joint #158 2:30 6:00 3.5 M/U hanger and landing joint. Landed same &CBU. RU cement lines. Held PJSM. Flush lines with 3 BBL water PT lines to 4000 PSI. With rig pumped 25 BBL Mud push XL, shut down and batch up 12.8 PPG cement, Pump 111 BBL Lead Cement Slurry @ 12.8 PPG, followed by 29 BBL Tail Cement Slurry @ 15.8 PPG, Shut down, wash lines and drop plug. Pump 5 BBL mix water followed by 243 BBL mud pumped by rig, bumped plug at 05:47 HRS 6:00 7:00 1.0 Pressured up after bumping plug to 3500 PSI held for 30 minutes bled pressure off and checked floats had a total of 3 BBL return 7:00 8:00 1.0 RD Cement head, LD landing joint, clean floor. 8:00 9:30 1.5 Install 7" casing pack off and test to 5000 PSI held for 10 minutes, and install short wear ring 9:30 13:00 3.5 LD 5" HWDP. 13:00 13:30 0.5 RD Horizon crown sensor, Brk out drive sub XO from 7" landing joint 13:30 14:00 0.5 PU Bit, 7" casing scraper, Bit sub and XO 14:00 19:00 5.0 RIH with scraper assembly 19:00 19:30 0.5 Tag up at 6463' kelly up and rotate to 6475' Initially very hard had to set down 8-9K on bit and drilled off very slowly (1800-2100 Torque) broke through and drilled relatively easy from there. At or near BU from initial hard spot had rubber come across shaker screen. 19:30 21:00 1.5 CBU, finish cleaning pits, and flush lines 21:00 22:30 1.5 PJSM with all parties involved in fluid change over, Test casing to 3500 PSI for 10 minutes with no pressure loss. Pump 75 BBL H2O followed by 50 BBL of dirt magnet chased by 150 NBBL of H2O followed by 50 BBL of KCL, chased by 65 BBL of H2O, taking returns to slop tank and centrifuge tanks. Water cleared up greatly after dirt magnet came back. KCL spotted at bottom of hole. 22:30 0:00 1.5 POOH LD DP 9/1 /04 From To Hours Remarks 0:00 5:00 5.0 POOH LD DP 5:00 6:00 1.0 Clean floor. Pull wear ring. 6:00 7:00 1.0 RU Schlumberger a-line 7:00 12:30 5.5 Run CBL, had to pull back out of hole at 5700' due to short in line. Rehead run back in well 6474' pressure casing to 1500 PSI and log out to 1925'. Top of cement appears to be at 2200', drop back down to 2400' and log back up to 1925' to verify TOC 12:30 13:00 0.5 RD SWS 13:00 14:30 1.5 Change out lower rams to 4.5", body test 250 PSI low and 3500 PSI high 14:30 15:30 1.0 RU WOTCO to run 4.5" tubing, hold PJSM prior to running pipe 15:30 18:30 3.0 RIH to 1611' had power pack problems 18:30 18:45 0.25 Change out power pack 18:45 21:00 2.25 RIH to 3609' 21:00 22:00 1.0 MU chemical injection line, hang control line sheave, and install chemical injection line. Pressure up line to 1000 PSI 22:00 0:00 2.0 RIH with 4.5" tubing, strapping 1/4" control line to tubing. RIH to 5113' BOP test waiver today at 16:38 by Winton Aubert with AOGCC. Test originally due today. Up 70M, DN 69M X-Nipple loaded with RHC plug KGSF-07 morning report summary, AFE 162678, CONFIDENTAL: last revised 12/15/2004 Page 7 9/2/04 From To Hours Remarks 0:00 1:30 1.5 Continue to RIH 1:30 4:00 2.5 Install tubing hanger, and landing joint, MU chemical injection line, drain BOP, land hanger and verify correct setting in tubing spool. Close bag and pressure up to 700 PSI to verify hanger body seals intact, bleed off pressure. PU hanger 4', RD WOTCO tongs, MU Safety valve, head pin, and HP hose 4:00 5:00 1.0 Circulate inhibited packer fluid, and diesel for freeze protection 5:00 6:00 1.0 Drop bar wait 15 minutes, pump approx 7.5 bbl to pressure up. Ran pressure up to 2500 PSI and let sit for a couple of minutes, pressured up to 3500 PSI and waited and pump would not roll over with this much pressure, bled pressure back to 500 PSI and ran pump up to 4200 PSI and pop off blew. Repinned valve and proceeded to pressure up again to 4000 PSI shut in and after 1 minute sitting the off duty pump pop off blew (pump not isolated). Isolated pump and pressured up to 400 PSI and let sit for 10 minutes. Bled pressure off. Note all pumping was done with annulus valve open. (Packer setting) 6:00 7:30 1.5 Run 2" HP hose to cellar and connect to annulus. With TIW open pressure annulus to 2500 PSI and hold for 30 minutes, had approximately 20 PSI drop in pressure during test. Bled pressure off. 7:30 8:30 1.0 Break out TIW and head pin, lay down landing joint and install 4" Type H BPV 8:30 13:30 5.0 Remove catch can and tarp, wash down BOP, open doors and removal all rams, NP bell nipple and flow line, pull rotary table 13:30 18:30 5.0 Clean and remove koomey lines, remove choke and kill lines, NP BOP 18:30 21:00 2.5 NU dry hole tree, Test 11" 5M tubing head adapter to 5000 PSI, Pull 4" Type H BPV and install 4" Type H TWC and attempt to test tree to 5000 PSI. Was not able to hold pressure, removed TWC and redressed, installed same and tested again to 5000 PSI held good. Removed TWC and installed BPV and secured well. Released rig at 21:00 HRS 21:00 23:00 2.0 Pumped packing in 16" x 9 5/8" void area of wellhead until solid, PT to 3000 PSI held for 30 minutes 23:00 0:00 1.0 Peak loading trailers and readying equipment for demob. 9/3-6/04 From To Hours Remarks 0:00 24:00 24.0 RD/MO 10/17/04 From To Hours Remarks 0:00 8:00 8.0 No activity 8:00 .9:00 1.0 Schlumberger on location, still pulling pit liner to prep., Spot vac truck with lease water for testing. 9:00 13:00 4.0 Spot unit, PJSM, RU, stab injector head & test hard lines. Prime G pump and fill coil. Test BOP 300# low and 3700# high (OK). 13:00 14:30 1.5 RIH with coil checking pick up weight every 1500', start cooling down N2 and start pumping 300 SCFM at 3000' RKB. Continue RIH and set down on bottom at 6471' coil measurement and pick up free, no extra weight. Reciprocate pipe above bottom and wait on N2 to make corner. 14:30 15:30 1.0 Circulate N2 while on bottom from 300 SCFM to 500 SCFM. Strap Johnson tank after returns are free of fluid and recovered 122 Bbl of fluid unloaded. 15:30 17:00 1.5 Shut in returns and pump 300 SCFM while POOH. 17:00 17:30 0.5 Close swab valve and both masters with 2600# of N2 on tubing. 17:30 21:30 4.0 Blow down and bleed down surface equipment. RD 10/24/04 From To Hours Remarks 0:00 8:00 8.0 Operation suspended 8:00 10:00 2.0 Schlumberger in field at 8:00 hrs, spot equipment 10:00 10:30 0.5 Change out tree top flange KGSF-07 morning report summary, AFE 162678, CONFIDENTAL: last revised 12/15/2004 Page 8 10:30 11:45 1.25 Pick up~icator, pre job safety and operations mee~, review Unocal perforating checklist. Arm 10' 3-3/8" 6spf HSD perforating gun with 8" loaded, stab lubricator, test same to 4200'. 11:45 12:45 1.0 RIH with perforating gun and CCL, noted fluid level at 5930', tie into Schlumberger CH CBL log dated 9-1-04, log on depth perforate 6375' to 6383' 12:45 15:00 2.25 POH, all shots fired, RD Schlumberger Well released to production KGSF-07 morning report summary, AFE 162678, CONFIDENTAL: last revised 12/15/2004 Page 9 w° _- SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00215 Sidetrack No~ Page , of , Company UNOCAL Rig Contractor & No. Kuukpik - 5 Field SWANSON RIVER Well Name & No. KGSF#7~ Survey Section Name Definitive Survey BHI Rep. ERIC BROWN ,ME~ WELL DATA Target TVD (~ Target Coord. N/S Slot Coord. N/S 0.00 Grid Correction 0.000 Depths Measured From: RKB ® MSL Q SSQ Target Description Target Coord. E/W Slot Coord. E/W 0.00 Magn. Declination 20.190 Calculation Method MINIMUM CURVATURE Target Direction (oo> Build\Walk\DL per: 100ft® 30mO tOm~ Vert. Sec. Azim. 17.26 Magn. to. Map Corr. 20.190 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Type Depth (Fn Angle (~~) Direction (oo) Length l~l TVD (Fn Section N(+) / S(-) (~1 E(+) / W(-) (Fn DL (Per 100 Fl') Build (+) Drop (-) Right (+) Left. (-) Comment MWD 2061.00 0.35 52.91 2060.96 -5.81 -7.93 5.91 TIE IN POINT UG-04 MWD 2127.00 0.35 13.15 66.00 2126.96 -5.46 -7.61 6.12 0.36 0.00 26-AUG-04 MWD 2189.00 0.53 154.83 62.00 2188.96 -5.48 -7.69 6.28 1.34 0.29 26-AUG-04 MWD 2315.00 0.70 160.10 126.00 2314.95 -6.52 -8.94 6.79 0.14 0.13 26-AUG-04 MWD 2440.00 0.62 186.12 125.00 2439.94 -7.79 -10.33 6.98 0.25 -0.06 26-AUG-04 MWD 2565.00 0.44 174.87 125.00 2564.94 -8.90 -11.48 6.95 0.17 -0.14 26-AUG-04 MWD 2692.00 0.53 152.72 127.00 2691.93 -9.77 -12.49 7.26 0.16 0.07 26-AUG-04 MWD 2819.00 0.53 168.19 127.00 2818.93 -10.70 -13.58 7.65 0.11 0.00 26-AUG-04 MWD 3263.00 0.44 170.65 444.00 3262.91 -14.02 -17.28 8.35 0.02 -0.02 27-AUG-04 MWD 3760.00 0.26 164.35 497.00 3759.90 -16.67 -20.24 8.96 0.04 -0.04 27-AUG-04 MWD 4077.00 0.18 126.35 317.00 4076.90 -17.44 -21.23 9.56 0.05 -0.03 28-AUG-04 MWD 4328.00 0.44 66.94 251.00 4327.90 -16.95 -21.09 10.76 0.15 0.10 28-AUG-04 MWD 4575.00 0.62 66.94 247.00 4574.88 -15.47 -20.19 12.87 0.07 0.07 UG-04 MWD 4823.00 0.79 45.85 248.00 4822.57 -13.10 -18.48 15.33 0.12 0.07 - UG-04 MWD 5079.00 1.05 51.12 256.00 5078.83 -9.60 -15.78 18.42 0.11 0.10 28-AUG-04 MWD 5331.00. 1.14 49.71 252.00 5330.79 -5.57 -12.71 22.13 0.04 0.04 28-AUG-04 MWD 5582.00 0.88 53.58 251.00 5581.75 -1.91 -9.95 25.58 0.11 -0.10 28-AUG-04 MWD 5833.00 0.88 46.90 251.00 5832.72 1.32 -7.49 28.54 0.04 0.00 28-AUG-04 MWD 6083.00 0.97 48.66 250.00 6082.69 4.79 -4.78 31.53 0.04 0.04 29-AUG-04 MWD 6336.00 0.97 31.78 253.00 6335.65 8.69 -1.54 34.27 0.11 0.00 29-AUG-04 MWD 6480.00 0.97 32.49 144.00 6479.63 11.05 0.52 35.57 0.01 0.00 29-AUG-04 MWD 6530.00 0.97 32.49 50.00 6529.62 11.87 1.24 36.02 0.00 0.00 PROJECTION TO TD SEIKFR SURVEY CALCULATION AND FIELD WORKSHEET yob No: 0450-00215 Sidetrack No. Page , of 5 Company UNOCAL Rig Contractor & No. Kuukpik - 5 Field SWANSON RIVER Well Name & No. KGSF#7 Survey Section Name Definitive Survey BHI Rep. E BROWN / D BALLOU ~~ WELL DATA Target TVD (~ Target Coord. N/S Slot Coord. N/S 0.00 Grid Correction 0.000 Depths Measured From: RKB ® MSL Q SS~ Target Description Target Coord. E/W Slot Coord. E/W 0.00 Magn. Declination 20.190 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft® 30m0 10mQ Vert. Sec. Azim. 17.26 Magn, to Map Corr. 20.190 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Type Depth (~ Angle (DD) Direction (DD) Length (~ TVD (~ Section N(+) / S(-) (Fn E(+) / W(-) (~ DL (Per goo ~ Build (+) Drop (-) Right (+) Left (-) Comment 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT -AUG-04 GMS 50.00 0.15 232.67 50.00 50.00 -0.05 -0.04 -0.05 0.30 0.30 13-AUG-04 GMS 100.00 0.15 270.31 50.00 100.00 -0.13 -0.08 -0.17 0.19 0.00 13-AUG-04 GMS 150.00 0.12 169.16 50.00 150.00 -0.19 -0.13 -0.23 0.42 -0.06 13-AUG-04 GMS 200.00 0.44 173.09 50.00 200.00 -0.41 -0.37 -0.19 0.64 0.64 13-AUG-04 GMS 250.00 0.46 150.13 50.00 250.00 -0.72 -0.74 -0.07 A.36 0.04 13-AUG-04 GMS 300.00 0.55 153.59 50.00 300.00 -1.03 -1.13 0.14 0.19 0.18 13-AUG-04 GMS 350.00 0.54 154.16 50.00 349.99 -1.38 -1.55 0.35 0.02 -0.02 13-AUG-04 GMS 400.00 0.52 153.00 50.00 399.99 -1.71 -1.97 0.55 0.05 -0.04 13-AUG-04 GMS 450.00 0.45 149.78 50.00 449.99 -2.01 -2.34 0.75 0.15 -0.14 13-AUG-04 GMS 500.00 0.50 160.03 50.00 499.99 -2.32 -2.71 0:93 0.20 0.10 13-AUG-04 GMS 550.00 0.43 148.51 50.00 549.99 -2.61 -3.08 1.10 0.23 -0.14 13-AUG-04 GMS 600.00 0.40 132.15 50.00 599.98 -2.81 -3.36 1.33 0.24 -0.06 AUG-04 GMS 650.00 0.47 154.11 50.00 649.98 -3.03 -3.66 1.55 0.36 0.14 -AUG-04 GMS 700.00 0.37 151.95 50.00 699.98 -3.30 -3.98 1.71 0.20 -0.20 13-AUG-04 GMS 750.00 0.41 146.77 50.00 749.98 -3.52 -4.28 1.89 0.11 0.08 13-AUG-04 GMS 800.00 0.30 131.63 50.00 799.98 -3.69 -4.51 2.08 0.29 -0.22 13-AUG-04 .GMS 850.00 0.30 141.98 50.00 849.98 -3.82 -4.70 2.26 0.11 0.00 13-AUG-04 GMS 900.00 0.18 180.50 50.00 899.98 -3.97 -4.88 2.34 0.39 -0.24 13-AUG-04 GMS 950.00 0.25 146.36 50.00 949.98 -4.11 -5.05 2.40 0.29 0.14 13-AUG-04 GMS 1000.00 0.26 163.72 50.00 999.98 -4.28 -5.25 2.49 0.16 0.02 13-AUG-04 GMS 1050.00 0.24 166.33 50.00 1049.98 -4.46 -5.46 2.55 0.05 -0.04 13-AUG-04 GMS 1100.00 0.31 160.61 50.00 1099.98 -4.66 -5.69 2.62 0.15 0.14 13-AUG-04 GMS 1150.00 0.26 155.71 50.00 1149.98 -4,85 -5.92 2.71 0.11 -0.10 >Re>~>~>Q SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00215 Sidetrack No. Page 2 of 5 ~~ ~~v Company UNOCAL Rig Contractor & No. Kuukpik - 5 Field SWANSON RIVER Well Name & No. KGSF#7 Survey Section Name Definitive Survey BHI Rep. EBROWN / D BALLOU ~~ WELL DATA Target TVD (~ Target Coord. N/S Slot Coord. N/S 0.00 Grid Correction 0.000 Depths Measured From: RKB ® MSL 0 SSQ Target Description Target Coord. E/W Slot Coord. EM/ 0.00 Magn. Declination 20.190 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30mO 10m0 Vert. Sec, Azim. 17.26 Magn. to Map Corr. 20.190 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date -Tool Type Depth (~ Angle (DD) Direction (DD) Length (~ TVD (~ Section N(+) / S(-) (~ E(+) / W(-) (~ DL (Per ioo ~ Build (+) Drop (-) Right (+) Left (-) Comment 13-AUG-04 GMS 1200.00 0.32 130.40 50.00 1199.98 -4.99 -6.12 2.86 0.28 0.12 AUG-04 GMS 1250.00 0.20 151.55 50.00 1249.97 -5.11 -6.29 3.01 0.30 -0.24 13-AUG-04 .GMS 1300.00 0.18 180.61 50.00 1299.97 -5.25 -6.44 3.05 0.19 -0.04 13-AUG-04 GMS 1350.00 0.16 139.66 50.00 1349.97 -5:36 -6.57 3.10 0.24 -0.04 13-AUG-04 GMS 1400.00 0.34 168.73 50.00 1399.97 -5.53 -6.77 3.17 0.43 0.36 13-AUG-04 GMS 1450.00 0.28 159.78 50.00 1449.97 -5.75 -7.03 3.24 0.15 -0.12 13-AUG-04 GMS 1500.00 0.28 142.14 50.00 1499.97 -5.92 -7.24 3.36 0.17 0.00 13-AUG-04 GMS 1550.00 0.25 113.02 50.00. 1549.97 -6.00 -7.38 3.53 0.27 -0.06 13-AUG-04 GMS 1600.00 0.32 118.44 50.00 1599.97 -6.04 -7.49 3.76 0.15 0.14 13-AUG-04 GMS 1650.00 0.23 141.25 50.00 1649.97 -6.12 -7.64 3.94 0.28 -0.18 13-AUG-04 GMS 1700.00 0.24 142.35 50.00 1699.97 -6.24 -7.80 4.07 0.02 0.02 13-AUG-04 GMS 1750.00 0.45 110.64 50.00 1749.97 -6.31 -7.95 4.32 0.55 0.42 13-AUG-04 GMS 1800.00 0.39 154.38 50.00 1799.97 -6.45 -8.17 4.57 0.64 -0.12 UG-04 GMS 1850.00 0.24 131.35 50.00 1849.97 -6.61 -8.39 4.73 0.39 -0.30 -AUG-04 GMS 1900.00 0.19 73.81 50.00 1899.97 -6.61 -8.44 4.89 0.42 -0.10 13-AUG-04 GMS 1931.00 0.50 68.84 31.00 1930.97 .6.5Q -8.38 •5.06 1.00 1.00 13-AUG-04 MWD 2061.00 0.35 52.91 130.00 2060.96 -5.82 -7.93 5.91 0.15 -0.12 13-AUG-04 MWD .2125.00 2.37 4.16 64.00 2124.94 -4.38 -6.50 6.16 3.37 3.16 l~+is Nn~E See~r.H ~` 13-AUG-04 MWD 2187.00 4.35 1.09 62.00 2186.83 -0.87 -2.87 6.30 3.21 3.19 •D P *~ A w ~ Cr`+nen f M 13-AUG-04 MWD 2250.00 6.57 0.38 63.00 2249.54 4.88 3.13 6.37 3.53 3.52 -1.13 KGSF ~'-/ G¢oM 2~~0~ ro 13-AUG-04 MWD 2313.00 9.09 1.12 63.00 2311.95 13.11 11.71 6.49 4.00 4.00 1.17 ~8~lG ~ 13-AUG-04 MWD 2376.00 11.15 3.19 63.00. 2373.97 23.80 22.77 6.92 3.32 3.27 3.29 13-AUG-04 MWD 2438.00 12.98 7.38 62.00 2434.60 36.47 35.66 8.15 3.27 2.95 6.76 13-AUG-04 MWD 2501.00 14.50 13.30 63.00 2495.79 51.31 50.35 10.87 3.28 2.41 9.40 w~ ~~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00215 Sidetrack No. Page 3 of b Company UNOCAL Rig Contractor & No. Kuukpik - 5 Field SWANSON RIVER Well Name & No. KGSF#7 Survey Section Name .Definitive Survey BHI Rep. EBROWN / D BALLOU ,~~ WELL DATA Target TVD (~ Target Coord. N/S Slot Coord. N/S 0.00 Grid Correction 0.000 Depths Measured From: RKB ® MSL~ SSD Target Description Target Coord. E/W Slot Coord. E/W 0.00 Magn. Declination 20.190 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft® 30m~ 1Om0 Vert. Sec. Azim. 17.26 Magn. to Map Corr. 20.190 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate. Build Rate Walk Rate Date Tool Type Depth (~7 Angle (DD) Direction (~~) Length (Fn TVD (F~l Section N(+) / S(-) (Fn E(+) / W(-) (F1) DL (Per ioo ~ Build (+) Drop (-) Right (+) Left (-) Comment 13-AUG-04 MWD 2564.00 16.31 15.36 63.00 2556.53 68.02 66.56 15.03 3.00 2.87 3.27 UG-04 MWD 2626.00 18.61 15.52 62.00 2615.67 86.62 84.49 19.99 3.71 3.71 0.26 14-AUG-04 MWD 2691.00 20.80 14.64 65.00 2676.86 108.51 105.65 25.68 3.40 3.37 -1.35 14-AUG-04 MWD 2753.00 22.75 13.76 62.00 2734.43 131.48 127.95 31.31 3.19 3.15 -1.42 14-AUG-04 MWD 2817.00 25.87 14.81 64.00 2792.75 157.79 153.47 37.83 4.92 4.87 1.64 14-AUG-04 MWD 2881.00 27.30 16.79 64.00 2849.98 186.42 181.03 45.64 2.63 2.23 3.09 14-AUG-04 MWD 2943.00 30.03 17.22 62.00 2904.38 216.15 209.46 54.34 4.42 4.40 0.69 14-AUG-04 MWD 3007.00 30.72 17.38 64.00 2959.59 248.51 240.36 63.96 1.09 1.08 0.25 14-AUG-04 MWD 3070.00 30.39 17.23 63.00 3013.85 280.54 270.94 73.49 0.54 -0.52 -0.24 14-AUG-04 MWD 3133.00 30.15 17.01 63.00 3068.26 312.30 301.29 82.84 0.42 -0.38 -0.35 14-AUG-04 MWD 3198.00 30.90 17.24 65.00 3124.25 345.31 332.84 92.56 1.17 1.15 0.35 14-AUG-04 MWD 3261.00 30.98 17.08 63.00 3178.28 377.70 363.79 102.12 0.18 0.13 -0.25 14-AUG-04 MWD 3325.00 30.62 17.05 64.00 3233.26 410.47 395.11 111.73 0.56 -0.56 -0:05 UG-04 MWD 3389.00 30.14 17.11 64.00 3288.47 442.84 426.05 .121.24 0.75 -0.75 0.09 -AUG-04 MWD 3453.00 31.58 15.65 64.00 3343.41 475.66 457.55 130.49 2.54 2.25 -2.28 ~ ', ~Gr~ {~ocC s~~ ~~oH P . ~9 14-AUG-04 MWD 3515.00 32.23 14.42 62.00 3396.04 508.40 489.19 138.98 1.48 1.05 -1.98 ~ ~e.x ~. 14-AUG-04 MWD 3577.00 31.52 16.64 62.00 3448.69 541.12 520.74 147.74 2.21 -1.15 3.58 14-AUG-04 MWD 3640.00 31.09 17.49 63.00 3502.52 573.86 552.03 157.35 0.98 -0.68 1.35 14-AUG-04 MWD 3704.00 30.55 17.55 64.00 3557.48 606.65 583.30 167.22 0.85 -0.84 0.09 14-AUG-04 MWD 3767.00 30.26 17.11 63.00 3611.82 638.53 613.73 176.72 0.58 -0.46 -0.70 14-AUG-04 MWD 3831.00 30.07 17.31 64.00 3667.15 670.69 644.45 186.23 0.34 -0.30 0.31 14-AUG-04 MWD 3895.00 29.79 17.11 64.00 3722.62 702.62 674.96 .195.68 0.46 -0.44 -0.31 14-AUG-04 MWD 3959.00 30.51 16.13 64.00 3777.96 734.76 705.76 204.87 1.36 1.13 -1.53 14-AUG-04 MWD 4021.00 30.59 15.76 62.00 3831.35 766.27 736.06 213.53 0.33 0.13 -0.60 ~`~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-002,5 Sidetrack No. Page 4 of 5 Company UNOCAL Rig Contractor & No. Kuukpik - 5 Field SWANSON RIVER Well Name & No. KGSF#7 Survey Section Name Definitive Survey BHI Rep. EBROWN / D BALLOU INTL'~CiZ WELL DATA Target TVD (Fn Target Coord. N/S .Slot Coord. N/S 0.00 Grid Correction 0.000 Depths Measured From: RKB ® MSL 0 SSQ Target Description Target Coord. E/W Slot Coord. E/W 0.00 Magn. Declination 20.190 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft® 30m0 10m0 Vert. Sec. Azim. 17.26 Magn. to Map Corr. 20.190 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Type Depth (~ Angle (DD) Direction (DD) Length (~ TVD (~ Section N(+) / S(-) (F~ E(+) / W(-) (~ DL (Per 100 FT) Build (+) Drop (-) Right (+) Left (-) Comment 14-AUG-04 MWD 4084.00 30.33 15.74 63.00 3885.66 798.20 766.80 222.20 0.41 -0.41 -0.03 "` UG-04 MWD 4148.00 29.87 15.96 64.00 3941.03 830.28 797.67 230.96 0.74 -0.72 0.34 14-AUG-04 MWD 4211.00 29.48 15.98 63.00 3995.76 861.46 827.66 239.54 0.62 -0.62 0.03 14-AUG-04 MWD 4273.00 29.15 15.59 62.00 4049.82 891.81 856.87 247.80 0.61 -0.53 -0.63 15-AUG-04 MWD 4335.00 29.38 16.15 62.00 4103.91 922.11 886.02 256.09 0.58 0.37 0.90 15-AUG-04 MWD 4397.00 29.46 16.29 62.00 4157.91 952.56 915.27 264.60 0.17 0.13 0.23 15-AUG-04 MWD 4459.00 29.32 16.04 62.00 4211.94 982.98 944.49 273.07 0.30 -0.23 -0.40 15-AUG-04 MWD 4520.00 28.11 16.37 61.00 4265.43 1012.28 972.63 281.25 2.00 -1.98 0.54 15-AUG-04 MWD 4582.00 27.35 17.74 62.00 4320.31 1041.13 1000.21 289.70 1.60 -1.23 2.21 16-AUG-04 MWD 4644.00 24.70 20.64 62.00 4376.02 1068.31 1025.90 298.61 4.74 -4.27 4.68 16-AUG-04 MWD 4706.00 21.64 19.93 62.00 4433.02 1092.66 1048.78 307.07 4.96 -4.94 -1.15 16-AUG-04 MWD 4768.00 20.22 19.75 62.00 4490.92 1114.79 1069.61 314.59 2.29 -2.29 -0.29 16-AUG-04 MWD 4830.00 18.71 17.94 62.00 4549.38 1135.44 1089.16 321.28 2.62 -2.44 -2.92 - 7~i) ~1o~,e St cL~rh UG-04 MWD 4894.00 16.88 17.69 64.00 4610.31 1155.00 1107.78 327.26 2.86 -2.86 -0.39 L~,~ -AUG-04 MWD 4958.00 15.01 18.05 64.00 4671.85 1172.58 1124.51 332.65 2.93 -2.92 0.56 16-AUG-04 MWD 5022.00 12.82 18.38 64.00 4733.97 1187.96 1139.13 337.46 3.42 -3.42 0.52 16-AUG-04 MWD 5086.00 11.01 17.97 64.00 4796.59 1201.17 1151.68 341.59 2.83 -2.83 -0.64 16-AUG-04 MWD 5149.00 9.33 10.59 63.00 4858.60 1212.26 1162.43 344.38 3.37 -2.67 -11.71 16-AUG-04 MWD 5212.00 7.63 7.34 63.00 4920.91 1221.46 1171.60 345.85 2.80 -2.70 -5.16 16-AUG-04 MWD 5275.00 5.86 2.98 63.00 4983.47 1228.69 1178.96 346.56 2.92 -2.81 -6.92 16-AUG-04 MWD 5338.00 4.12 3.39 63.00 5046.23 1234.01 1184.43 . 346.86 2.76 -2.76 16-AUG-04 MWD 5401.00 3.31 5.62 63.00 5109.09 1237.99 1188.50 347.17 1.31 -1.29 . 16-AUG-04 MWD 5463.00 3.22 6.68 62.00 5170.99 1241.45 1192.01 347.55 0.17 -0.15 16-AUG-04 MWD 5526.00 3.30 .4.03 63.00 5233.89 1244.96 1195.57 347.88 0.27 0.13 RoYF~, SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00215 Sidetrack No. Page 5 of 5 w ~~~ Company UNOCAL Rig Contractor & No. Kuukpik - 5 Field SWANSON RIVER Well Name & No. KGSF#7 ~ Survey Section Name Definitive Survey BHI Rep. EBROWN / D BALLOU j~ WELL DATA Target TVD IFn Target Coord. N/S Slot Coord. N/S 0.00 Grid Correction 0.000 Depths Measured From: RKB ® MSLD SSD Target Description Target Caord. E/VV Slot Coord. E/W 0.00 Magn. Declination 20.190 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft® 30mO 10m0 Vert. Sec. Azim. 17.26 Magn. to Map Corr. 20.190 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Type Depth (~ Angle fog) Direction (~o) Length (F~ TVD (~ Section N(+) / S(-) (~) E(+) / W(-) (~1 DL (Per 100 F~ Build (+) Drop (-) Right (+) Left (-) Comment 16-AUG-04 MWD 5586.00 3.24 7.73 60.00 5293.79 1248.31 1198.98 348.23 0.37 -0.10 UG-04 MWD 5653.00 3.20 9.06 67.00 5360.69 1252.03 1202.70 348.78 0.13 -0.06 16-AUG-04 MWD 5716.00 2.97 9.20 .63.00 5423.60 1255.38 1206.05 349.32 0.37 -0.37 16-AUG-04 MWD 5778.00. 2.92 12.96 62.00 5485.51 1258.55. 1209.17 349.93 0.32 -0.08 17-AUG-04 MWD 5840.00 2.92 11.51 62.00 5547.43 1261.69 1212.26 350.60 0.12. 0.00 17-AUG-04 MWD 5903..00 2.74 13.64 63.00 5610.36 1264.79 1215.29 351.27 0.33 -0.29 17-AUG-04 MWD 5967.00 2.60 10.43 64.00 5674.29 1267.76 1218.21 351.90 0.32 -0.22 17-AUG-04 MWD 6029.00 2.45 13.19 62.00 5736.23 1270.48 1220.88 352.45 0.31 -0.24 17-AUG-04 MWD 6091.00 227 13.80 62.00 5798.17 1273.03 1223.36 353.05 0.29 -0.29 17-AUG-04 MWD 6154.00 2.28 19.98 63.00 5861.12 1275.53 1225.75 353.77 0.39 0.02 17-AUG-04 MWD 6218.00 2.40 21.33 64.00 5925.07 1278.13 1228.20 354.70 021 0.19 17-AUG-04 MWD 6281.00 2.37 17.95 63.00 5988.02 1280.75 1230.67 355.58 0.23 -0.05 17-AUG-04 MWD 6345.00 2.50 22.63 64.00 6051.96 1283.46 1233:21 356.52 0.37 020 UG-04 MWD 6408.00 2.43 19.90 63.00 6114.90 1286.17 1235.74 357.51 0.22 -0.11 -Ti,;, N~ Sc ~~~+ -AUG-04 MWD 6470.00 2.31 24.59 62.00 6176.85 1288.72 1238.11 358.47 0.37 -0.19 ? * ~ D 17-AUG-04 MWD 6533.00 2.30 22.04 63.00 6239.80 1291.24 1240.44 359.48 0.16 -0.02 17-AUG-04 MWD 6595.00 2.28 27.22 62.00 6301.75 1293.69 1242.69 360.51 0.34 -0.03 17-AUG-04 MWD 6657.00 2.11 27.53 62.00 6363.70 1296.03 1244.79 361.60 027 -027 17-AUG-04 MWD 6720.00 1.99 25.75 63.00 6426.66 1298.25 1246.81 362.61 0.22 -0.19 17-AUG-04 'MWD 6782.00 2.09 29.39 62.00 6488:62 1300.42 1248.76 363.63 0.26 0.16 18-AUG-04 MWD 6800.00 2.08 27.18 18.00 6506.61 1301.07 1249.34 363.94 0.45 -0.06 18-AUG-04 MWD 6846.00 2.08 27.18 46.00 6552.58 1302.71 1250.82 364.70 0.00 0.00 PROJECTION TO TD Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com CtC `76, ~1-~6~ ~~~ a ©' ~ ~-~` lhd ~aZ~ /~a-o 5 ~~p~~ z Debra Oudean G & G Technician To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 Date: November 29, 2004 WELL I LOG TYPE _ SCALE LOG DATE ~ LOGGED B CD LINE ~KUSF 7A PERFORATING RECORD 3 3/8 HSD UUN ~ ~5 INCH 10/24/20 16100-6450 1 (1 ASCU 24A 05 PPLUG SET RECORD 2 7/8 HALLIBURTON EZSV ~5 INCH f 10/21/2004 _ __ f9 - ~ 1 j 1 I ASCU 24A 05 iSOUEEZE PERFORATION RECORD 2 HSD 2006 PJ 6spf ,: _.. I5 INCH 10/29/2004 7626 7800 ~ 1 ~ 1 ,ASCU 24A 05 _ _ (HALLIBURTON CEMENT RETAINER ~ f 5 INCH ~ 10/30/2004 , 7100-7600 . I 1 ~ 1J ~SCU 312-09 SLIM CEMENT MAP TOOL ~5 INCH 10/21/2004 4300-7300 i 1 1 1 SCU 312-09 _ COMPLETION RECORD 2 HSD POWERJET _„ ~5INCH 11/2/2004 6990-6340 ~ 1 1 ~ ASCU 32 08 COMPLETION RECORD 2 5 HSD POWERET 6SPF 60 5 INCH _ 10/3/2004 10200-10565 ;{ 1 1 DEGREE PHASED J 43B 08 COMPLETION RECORD 2 5 HSD POWERJETS ~5 INCH 11/3/2004 5857-5867 J 23 27 ~HALLIBURTON GUN CORRELATION LOG RESERVOIR ~5 INCH 10/17/20045100-7760 SATURATION TOOL _____ ._ ~j~~Dg~ ;SRU 32A 15 Y ._ _..._._ _. ___._ ! CEMENT TOP TEMP SURVEY GR/CCL __.._._ _......__ _._:..._ _.__.... ~ 1/5 INCH { 9/27/2004 0 9600 I /r~,y-~~~SRU 32A-15 l-! '.; __..._._ COMPLETION RECORD 2 HSD POWERJET 6SPF 60 DEGREE PHASED _____ ~ 5 INCH _..__..~ _ _.. 9/30/2004 ~._____: 7280-7600 __. (R~`O~ RU 32A 15 COMPLETION RECORD 2 HSD POWERJET 6SPF 5 INCH 10/3/2004 6830 7345 HALLIBURTON EZ-DRILL BRIDGE PLUG Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. ~_ 1~_ ~_i~ 1 ~1 1:~1 1 ~1= 1 _ _. 1 ~1~ Date: ~ ~ ~d ~ ~C~ _ _ ,; STATE OF ALASKA A OIL AND GAS CONSERVATION COM ION APPL ATION FOR SUNDRY APP~VA L 20 AAC 25 280 ~"~t~~'p ~~~ Z 3 ZU04 1. Type of Request: Abandon Suspend Operational shutdown Perforate. ~ ~ ~;~r'a gla~~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension }101'~~6 Other ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to frill Number: ' Union Oil Company of California Develo ment p ^ Exploratory ^ ~ ~M _ 3. Address: Stratigraphic ^ Service Q 6. API Number: PO Box 196247, Anchorage, AK, 99516 50-133-20538~~ 7. KB Elevation (ft): 9. Well Name and Number: 24.74' RKB to GL KGSF #7a-' 8. Property Designation: 10. Field/Pools(s): A-028399 Swanson River Field / Tyonek 64-5 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): 6,530' 6,530' 6,478' 6,478' Open Hole Open Hale Casing Length Size MD ND Burst Collapse Structural Conductor 41 16 41 41 Surface 1985 9.625 1,950 1,950 5,750 psi 3,090 psi Intermediate Production 7 6,522 6,522 7,420 psi 5,410 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Open Hole Open Hole Open Hole NA NA Packers and SSSV Type: Baker Primier Packer 7" Packers and SSSV MD (ft): 6,077 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1 J18/ 004 Oil ^ Gas 0 Plugged ^ Abandoned ^ 16. Verbal Approval: Date : WAG ^ GINJ ^~ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chantal Walsh 263-7627 Printed Name Tim Brandenburg Title Drilling Manager Signature hone 263-7628 Date 10/13/2004 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ j Q ~.~,' " ?~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~ - ~ 7 APPROVED BY Approved by. COMMISSIONER THE COMMISSION Date: ~! Form 10-403 sed 0 004 Submit in Duplicate ~, ~ • • KGSF~Workover Summary ~~ • MIRU CT. PT BOPE. • RIH w/jet nozzle on CT. jet fluid out of well. / • RD CTU • RU Eline. RIH perf 64-5 sand 6375' to 6383'. • RD Eline. • • V N 0 CA ~ 76 S~~ a nson River Field KGSF #7A Final Completion Schematic Jewelry Detail 1. 41' 16" Drive Shoe 2. 1,950' 9-5/8" Surface Casing 3. 6,522' 7" Production Casing 4. 2,497' Chemical Injection Mandrell 5 . 6,113' 4-1 /2" Tubing 6. 6,077' Baker Primier Packer 7" - 26# 7. 6,097' BX Nipple 8. 6,112' WLEG Bit Sizes: 12-1/4", and 8-1/2" 9-5/8" Cemented to surface -Existing 7" Cemented to 1950' CASING DETAIL SIZE WT GRADE CONK TOP BOT'COM 16 68 K-55 BTC 0' 41' 9-5/8" 40 L-80 BTC 0' 1,950' T" 26 L-80 BTC 0' 6,522' TUBING DETAIL SIZE WT GRADE CONK 'TOP BOTTOM 4-1/2" 12.6 L-80 IBTC (AB Mod) 0' 6,113' Intended Perforations (Tyonek 64-5 Sand) Date LOG TYPE TOP BOTTOM 08/30/04 PEX 6,379' 6,387' 09/01/04 CBL 6,375' 6,383' Straight Hole: MD =TVD J TD = 6,530' MD / 6,530' TVD PBTD = 6,478' TVD / 6,478' TVD KGSF #7A FINAL REVISED: 10/13/04 DRAWN BY: SAM RKB to GL = 24.74' Tim Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99516 Re: Swanson River KGSF #7 Sundry Number: 304-379 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has rPPn rPnnPetPri BY ORDER OF THE COMMISSION DATED this~l day of October, 2004 Encl. • • ~~ ~ ~` ` FRANK H. MURKOWSKI GOVERNOR Phil Krueger Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska, 99519 Re: Swanson River KGSF #7A Union Oil Company of California Permit No: 204-163 Surface Location: 1999' FSL, 425' FEL, SEC. 28, T8N, R9W, S.M. Bottomhole Location: 1999' FSL, 425' FEL, SEC. 28, TBN, R9W, S.M. Dear Mr. Krueger: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Union Oil Company of California assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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) 65~~tj17 (pager). BY ORDER O~THE COMMISSION DATED this2i day of August, 2004 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 RECEIVED UNOCAL 76 auG ~.~ 2004 Alaska Oil & Gas Cons. Commission Anchorage Phil Krueger Wednesday, August 25, 2004 Drilling Manager Alaska Oil and Gas Conservation Commission 333 West 7`" Avenue Anchorage, Alaska 99501 Attn: Commission Chair John Norman Re: Application for Permit to Drill (Form 10-401) KGSF #7It; Dear Commissioner Norman, Attached for your approval is an application for permit to drill (Form 10-401) for the SRU ~o~ KGSF #71~. This is the second Permit to Drill for KGSF #7 as insufficient reservoir quality existed in the reservoir section drilled. Well operations are on going with the plug back of the 8-1/2" open hole section. The new well path is planned vertical. The anticipated spud date is today, Aug t 25.;2004. If you have any questions please contact myself at 263-7628 or Mr. Steven... afnbe at 263-7637. Sincerely, Phil Krueger Drilling Manager SSUs Enclosure ORIGINAL STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM .ION PERMIT TO DRILL 20 AAC 25.005 ~~~ ~12~/zc~e¢ ~~~rvE® AUG 2 ~ 2004 1a. Type of Work: Drill ~ Redrill Re-entry ~ 1b. Current Well Class: Exploratory De Stratigraphic Test ~ Service Q Development Ga~I1~Of$~~le Zone 2. Operator Name: Union Oil Company of California 5. Bond: Blanket ~ Sin le Well Bond No. (J6~ 6 11. Well Name and Number: KGSF #7A 3. Address: PO Box 196247, Anchorage, Alaska, 99519 6. Proposed Depth: MD: 6550 TVD: 6550 12. Field/Pool(s): Swanson River Field / Tyonek 4a. Location of Well (Governmental Section): Surface: 1999' FSL, 425' FEL, Sect. 28, T8N, R9W, S.M. 7. Property Designation: A-028399 64-5 Sand Top of Productive Horizon: 1999' FSL, 425' FEL, Sect. 28, T8N, R9W, S.M. 8. Land Use Permit: NA 13. Approximate Spud Date: 8/25/2004 / Total Depth: 1999' FSL, 425' FEL, Sect. 28, T8N, R9W, S.M. 9. Acres in Property: 1760 14. Distance to Nearest Property: 425 4b. Location of Well (State Base Plane Coordinates): Surface:x- 347290 y- 2468439.7 Zone- 4 10. KB Elevation (Height above GL): 20.5 feet 15. Distance to Nearest Well Within Pool: 230 16. Deviated wells: Kickoff depth: feet VertlCal Maximum Hole Angle: degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3300 Surface: 2217 18. Casing Program: Size Specifications Setting Depth Top Bottom Quantity of Cement c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD .(including stage data) 8.5 7 26 L-80 BTC 6550 0 0 6550 6550 580 ft cubed 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD ND Structural Conductor 41.00 16 Driven 41 41 Surface 1,985.00 9.625 Cemented to Surface 1985 1985 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch ~ Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Property Plat ~ Diverter Sketch ~ Seabed Report ~ Drilling Fluid Program Q 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Phil Krueger Title Drilling Manager Signature - Phone 263-7628 Date 8/25/2004 Commission Use Only Permit to Drill Number: ~(3 -~~j API Number: 50- 3~~ ,Z~„S,3 ~ -GS ~ Permit Approval Date: See cover letter for other requirements. Conditions of approval Samp r quired Yes ~ No Mud log required Yes ~ No Hy oge sulfide measures j Yes ~ No Directional urvery required yes ~ No Other: ~' ~"~ p O ~~Sdp ~SL - l~ LTA C2 ~'v~F-riC.t Ql(Cc,[it G/"~ ~"r'qu-,~ !/N of ~Y ORDER F cr / Approved b TH O MISSION Date: b Fo -401 ised 12!2003 Submit inDuplicate • • KGSF #7- Vertical Redrill of 8-112° OH Note: BOP test to 3500 psi Current: Next Due 8-28-04 ~ M/U 8 1/2" steerable BHA Drill out cement from casing (1985') and Sidetrack by 2300' Max Depth Drill 8 1/2" hole from: 1985' to: 6550' MD / 6550' TVD Circulate clean (& pump nut plug sweep) l POH w/ 8 1/2" BHA L/D BHA MIRU E-line RIH w/ Platform Express & Log full suite TD to 9-5/8", RD E-line RU & run 7" casing Land casing & circulate j Cement 7" casing w/ Lead & Tail. Planned TOC @ 9-5/8" shoe RD cementers & casing running equipment Set pack-off & test MU 6-1/8" C/O Bit and Casing Scraper. RIH to PBTD @ 6500'. Circulate Well Clean, Displace to Completion Brine Test 7" casing to 3,500 psi POOH & LD C/O BHA & DP RU E-line. Pull Bond Log. RD E-line PU &RIH 4-1/2" Completion w/ Hydo-Trip Packer Set packer and Test TBG & Casing to 3,500 psi Set BPV ND BOPE, NU & test tree to 5,000 psi, Clean tanks, L/D TDS & Hawkjaw Release Rig Note: Planned mud system Weight of 9.6 minimum to start with 10 ppg below 6,000' ND. • • V N ~ CA ~ 76 Swanson River Field KGSF #7 API # 50-133-20538, Permit to Drill # 204-081 Proposed Status -Abandoned RKB to GL = 20.50' A D 4.950' B C TD = 6,846' MD / 6,551' TVD Jewelry Detail 1. 41' 16" Drive Shoe 2. 1,985' 9-5/8" Surface Casing Bit Sizes: 12-1/4", and 8-1/2" 9-5/8" Cemented to surf CASING DETAIL SIZE WT GRADE CONN TOP BOTTOM 16" 68 K-55 BTC 0' 41' 9-5/8" 40 L-80 BTC 0' 1,985' Cement Plugs: A. 49 bbls, 17 ppg, 1,800' - 2,500' B. 71 bbls, 15.8 ppg, 4,950' - 5,900' C. 71 bbls, 15.8 ppg, 5,950' - 6,846' D. 9.8 ppg Drilling Mud Hydrocarbon Potential: 5,740' MD to TD Kick Off Isolation Isolation KGSF #7 OH REVISED: 08/25/04 DRAWN BY: SSL • uNOCa~~b Swanson River Field KGSF #7 Proposed Completion Revised Jewelry Detail 1. 41' 16" Drive Shoe 2. 1,985' 9-5/8" Surface Casing 3. 6,550' 7" Production Casing 4. 2,500' Chemical Injection Mandrell 5. 6,300' 4-1 /2" Tubing 6. 6,250' Retrievable Packer ~ 7. 6,275' X Nipple 8. 6,300' WLEG Bit Sizes: 12-1 /4", and 8-1 /2" 9-5/8" Cemented to surface -Existing 7" Cemented to 1985', Minimun of 580 ft-cube. CASING DETAIL J TD = 6,550' MD / 6,550' TVD SIZE WT GRADE CONN TOP BOTTOM 16 68 K-55 BTC 0' 41' ~-5/8" 40 L-80 BTC 0' 1,985' ~" 26 L-80 BTC 0' 6,831' TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 4-1/2" 12.6 L-80 IBTC (AB Mod) 0' 6,300' Perforations Date MD TVD TBD -Pending OH Logs KGSF #7 Proposed REVISED: 08/25/04 DRAWN BY: SSL RKB to GL = 20.50' • • Swanson River KGSF#7 9-5/8"" SHOE DESIGN SUMMARY & SKETCH METHOD 2: 9-5/8" shoe 1,814 ft BML (1,985 ft TVD) 1 1 1 8-1/2" Hole / - ` / 1 I RT-MSL=171.5ft -~~ I WD = 0 ft with 0.433 PSI/FT Gradient DESIGN DOWN: MW = 10 PPG Pform = 10 PPG EMW 9-5/8"shoe KT = 25.5 BBLS at 0 PPG FG = 0.842 PSI/FT Gas Gradient = 0.05 PSI/FT Drill Pipe = 4 INCH The shallowest 9-5/8"" shoe depth = 1,814 ft BML or 1,986 ft TVD The deepest 8-1/2 in hole that can be drilled = 6,483 ft BML or 6,654 ft TVD UNOCAL METHOD 1: 1 / 8-1/2" Hole / -` DESIGN UP: MW = 10 PPG Pform = 10 PPG EMW KT = 29 BBLS at 0 PPG FG = 0.842 PSI/FT Gas Gradient = 0.1 PSI/FT Drill Pipe = 4 INCH TD = 6,379 ft BML or 6,550 ftTVD / • • GENERAL INPUT DATA Field Swanson River Well Name KGSF#7 RT-MSL 171.5 ft Water Depth 0 ft Sea Water Gradient 0.433 psi/ft Casing Size to be Designed 9-5/8" Hole Size Drilled for This Casin 8-1/2 inch DESIGN METHOD 1: From TD up to find the shallowest allowable shoe depth Hole Size Below the Shoe 8-1 /2 inch Next Section Total Vertical Depth 6,550 ft TVD RKB Next Section Total Vertical Depth 6,379 ft TVD BML Next Section Gas Gradient (first approximation: 0.049) 0.100 psi/ft Kick Intensity cannot be less than 0 ppg 0.0 PPG Mud Weight 10.0 PPG Estimated Formation Pressure at Next Section TD 10.0 PPG EMW Fracture Gradient 0.84 psi/ft Kick Tolerance 29.0 bbl Drill Pipe Outside Diameter 4 inch Calculation results acceptable. Minimum shoe depth = 1,986 ft TVD RKB 1515 DESIGN METHOD 2: From upper casing shoe down to find the deepest hole which can be drilled without fracturing the upper casing shoe Upper Casing Size Upper Casing Shoe Depth 9-5/8 inch 1,985 ft TVD RKB Upper Casing Shoe Depth 1,814 ft TVD BML Upper Gas Gradient (first approximation: 0.016) 0.050 psi/ft Hole Size below the Upper Casing Shoe 8-1/2 inch Kick Intensity cannot be less than 0 ppg Mud Weight 0.0 PPG 10.0 PPG Estimated Formation Pressure 10.0 PPG EMW Fracture Gradient Kick Tolerance Drill Pipe Outside Diameter 0.84 psi/ft 25.5 bbl 4 inch Calculation results acceptable. Maximum shoe depth = 6,654 ft TVD RKB 5754 • • Maximum Anticipated Surface Pressure Calculation Swanson River Field KGSF#7- Revised Kenai Peninsula, Alaska Assumptions: 1. Based on offset drilling & well test data, the pore pressure gradient is predicted to be a 0.504 psi/ft gradient from surface to planned total depth at 6,550' VD BRT. 2. The M.A.S.P. during drilling operations will be governed by the 9 5/8" shoe frac gradient, and is calculated based on a full column of gas between the 9 5/8" shoe and the surface. 3. The M.A.S.P. during production operations will be the estimated SIBHP minus the gas hydrostatic pressure between TD & the surface. M.A.S. P. During Production Phase: Max. pore pressure at T.D. = 6,550 ' VD x 0.504 M.A.S.P. (tbg leak at surface) = 2849 psi - (0.096 psi/ft " 6,580 ft) _ Note: Above based on completed interval of 64-5 Sand when fully charged. M.A.S. P. During Drilling Phase: Actual Frac pressure at 9-5/8" shoe = 1985 ft. x 0.842 psi/ft = M.A.S.P. during drilling = 1671 psi - (.08 psi/ft x 1985 ft.) _ = 3301 psi = 2217 psi ~ = 1671 psi = 1513 psi Calculation & Casing Design Factors Swanson River Field KGSF#7- Revised Kenai Peninsula, Alaska WELL: KGSF#7 FIELD: Swanson River DATE: 25-Aug-04 DESIGN BY: Steven Lambe Sect. 1 12 1/4" hole MUD WT. 9.2 PPG MASP= 1,513 psi** Sect. 2 8-1/2" hole MUD WT. 10 PPG MASP= 2,217 psi TENSION MINIMUM COLLAPSE COLLAPSE WEIGHT TOP OF STRENGTH PRESS @ RESIST. MINIMUM DESCRIPTION W/O BF SECTION TENSION BOTTOM w/o TENSION MASP YIELD • SECTION CASING BOTTOM TOP LENGTH WT. GRADE T~IREAD LBS LBS 1000 LBS SF TENSION PSI* PSI SF COLL. PSI** PSI SF BURST 1 9 5/8" 1,985 0 1985 40 L-80 l BTC i 79,400 79,400 979 12.33 873 3090 3.54 921 5750 6.24 TVD " 1,985 0 / ~ ~ 2 7 6,550 0 6550 26 L-80 BTC-mod 170,300 170,300 519 2882 3.05 5410 1.88 1237 7240 5.85 TVD 6,550 0 * Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (.44 psi/ft) and the casing evacuated for the internal stress (0 psi/ft) ** See attached sheet for calculation of MASP Notes: 1. All wellhead components are rated to 5000 psi working pressure. ~~ • Property grids and formula's for KGSF #7- Revised Production Hole Recommendations Mud Type: 6% KCI, EZ Mud (PHPA) Properties: U Densit Viscosit Plastic Viscosity Yield Point API FL ~H CI- 1,985 -6,550' 9.6 - 40-55 8 - 20 13 - 25 < 5 8.5-9.0 28-30K ~.~° System Formulation: 6%KCI, EZ Mud Product Concentration Water 0.905 bbl KCI 19.8 ppb (28-30K chlorides) KOH 0.2 ppb (9 pH) Barazan D 1.25 ppb (as required 20 YP) Dextrid 1-2 ppb EZ Mud DP 0.75 ppb Aldacide G 0.1 ppb Baracor 700 1 ppb Barascav D 0.5 ppb (maintain per dilution rate) PAC L 2-3 ppb Baracarb As required Barite As re uired Baracarb would be strung into the system starting approximately '/z through the 8.5" hole. Plan to start with 9.6 to 9.8 ppg on initial drill out. Plan to have Mud Weight up to 10 ppg before drilling past 6,000' MD/VD. ~ • KGSF #7 BOP Stack Diagram Well Cellar • • 'Z ~~ 3ee To Shaker 3"Panic To Gasbuster Q 3 1 /8" ~ ~~i' -~ OO --00 O -- 2 1 /16" ~ ~ ~ 2 1 /16" u Q ~ O 2 1 /16~ O~ 2 1 /16" ~~ - O O O O --E- --~ OHO QO ~ ~ ~f 2 1 /16" ~ 2 1 /16" Manual Choke 4 ~ Automatic Choke I 2 ~/16 Inlet ressure Sensor See 3"5,000 PSI Choke N~nifold Kuulg~ik Dril ling Rig 5 RED = 3 1118'° 5,000 PSI VALVES AND LINES BLUE = 2 1/16" 5,000 PSI. VALVES SCALE KGSF #1 1 inch = 300 ft. FORMERLY 243-28 o soo a5o soo GRID. N: 2468635.116 GRID E: 347199.282 LATITUDE: 60'45'15.553"N LONGITUDE: 150'51'15.275"W PROPOSED KGSF #7 WELL SURFACE LOCATION AS STAKED KGSF #7 GRID N: 2,468,439.683. GRID E: 347,290.473 LATITUDE: 60°45'13.640"N LONGITUDE: 150°51'13.388"W ELEV. 151.4' SECTION 28 ' TOWNSHIP 8 NORTH RANGE 9 WEST '~ SEWARD MERIDIAN ALASKA '~ ``~~~~~~~~i ~~ ~~ .~ F A~q ~ ~l I .49 Iti............~* ~i ./ ~ ................................... j ~ ~ '•, M. SCOTT McLANE;' ~ ~ ~I~ ~`~~F~'• 4928-S •' _~ NOTES 1) BASIS OF COORDINATES: NGS CORS STATION "KEN 1" NAD27 ALASKA STATE PLANE ZONE 4. 2) BASIS OF ELEVATION: NGS BM Q79 RESET NAVD88. 3) SECTION LINE OFFSETS DERIVED FROM TIES TO BLM MONUMENTS AT CN 1/16, C 1/4 AND WC NE 1/16 SECTION 28 T8N R9W SM FOUND THIS SURVEY KGSF NO. 7 SURFACE LOCATION SWANSON RIVER FIELD, STERLING, AK I P.O. Box 468 SOLDOTNA, AK 99669 Project: 043026 ConsuLtiny C~'roup IV~cLane Testing Revisions: Dwg:043026 Date: 5/11/04 426'' FEL P&S YARD Grid _ SEC 28J SEC 27 SEC 33 SEC 34 APPLICANT: VNOCAL ~~ 909 W. 9th Avenue Anchorage, AK 99519-7685 FIGURE: 1 • • ,~ UNOCAL _ Location: Kenai Peninsula, Alaska(Imported) Slot: KGSF#7 (~' ~)'-~ ~ Field: Swanson River Unit Well: KGSF#7 Inatallatlon: PSS Yard Wellbore: KGSF#7 Rd Vers#1 ~ 1500 O tr) II 1800 U 2100 U 2400 2700 3000 3300 3600 w v 3900 Q d 4200 4500 L ~ 4800 3 L ~ 5100 V 5400 5700 6000 6300 6600 6900 7200 Created by : Planner Date plotted : 2SAUg-2004 Plot reference is KGSF#7 Rd Vers#1. Raf wellpath is KGSF#7 Rd Vers#1. Coordinates are in feat reference KGSF#7. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 173.90 ft. Plot North is aligned to TRUE North. le 1 cm = 50 ft East (feet) -> DO -100 0 100 200 300 400 500 1400 KGSF#7 1300 1200 1100 1000 900 800 700 ~.. 600 ~ 3 500 ~ r-r ... 400 300 KcsF#1 / KGSF#7Rd Target Rvsd 25-Aug-20 4 200 100 Target-TD 0 ~ ~ KGSF#7 Rtl Versiti ~ N -100 3 -200 u cn 0 -600 -300 -0 300 600 900 1200 1500 1800 Scale 1 cm = 150 ft Vertical Section (feet) -> Azimuth 89.26 with reference 0.00 N, 0.00 E from KGSF#7 CITIBANK DELAWARE 62-2o Q A Subsidiary oYCiticorp 3tt U(110f1 0l~ ~OlrlpaCiy Of California ~ Q ~ 7 8 ~ 3 ONE PENN'S WAY ACCOUt1t5 Pdyable Fleid plSbUrSing NEW CASTLE, DE 19720 Pay ****~***~*****~**~*~****~~*~**~~*~~~***~~~*~*~~~~*~~~~*~*~** One Hundred Dollars And OO Cents Date Check Amount 25-AUG-04 ~~**~*~**100.00 Ta the order STATE OF ALASKA Void after six monthsfrom above date. Of ALASKA OIL & GAS`. CONSERVATION COMMISSION :333 WEST 7TH AVENUE SUITE 100 ~ ~,l"1, ~~~ ANCHORAGE, AK 99501 , ry United States.. ~~ G "} +~~ ~i' 200 78 L 3~-'' ~:0 3 L iD0 i?0 9~: 3 9 L L8 L 3 7~~' • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# ~~ ~~ , Development Exploration Service Stratigraphic CHECK WAAT ADD-OHS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well Permit No, ~ API No. (If AP] number Production. should continue to be reported as last two. (2) digits a function~of the original API number, stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC Z5.005(f), all (PIS records, data and logs acquired for the pilot bole must be clearly differentiated ~in both name (name on permit plus PIS and API number (50 - 70/80) from records, dais and logs acquired for well (name on permit). SPACING The permit is approved subject ~to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing ~ exception. SCompany Name) assumes the liability of any protest io the spacing .exception that may occur. DRY DITCH ~ All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caugLt and ]0' sample intervals through target zones. WELL PERMIT-CHECKLIST Field & Pool SWANSON RIVER, GAS STORAGE - 772555 Well Name: SWANSON RIVER KGSF 7A Program SER Well bore seg ^ PTD#:2041630 Company UNION OIL CO OF CALIFORNIA Initial ClasslType SER ! GSTOR GeoArea 820 Unit 51994 OnlOff Shore Qn Annular Disposal ^ Administration 1 Pe[mR_fee attached- - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - 2 Lease numberappropriate- - - - - - - - - - - Yes - - - - - - - - 3 Unique well-name and number ------------------------------------- Yes. ---- --------------- ----------------------------------------------------- 4 Well located in a-defined pool___________________________-______-__- No-- --_--_SwansonRiverGas Storage Pool__--__-_--__-__- -_--_ 5 Well located paper distance from drilling unitboundary_ No- - _ _ _ - . _ 7A is located within 1500' of a property boundry, a spacing exception will be needbll t9ve ~tf~ d_ - - - _ 6 Well located proper distance from other wells . . . . .. . ... . . . .. . . . . .. . .. . . .. . . Yes - - - . t;~iR19 ~A. tof ~tJg~gr j w!~ regal dri'~rg the. - - _ . - 7 Sufficient acreage available in_dril_ling unit- _ _ Yes _ - bg 8 Ifdeyiated,is_wellboreplat-included----------------------------------- NA_- .• _-__-___ - -- - - 9 Ope[ator only affected party - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - 10 Ope[atorhas-appropriate.boDdNforce--------------------------------- Yes- ------------------ -------------------- ---------------------------- ----- 11 Permit-can be issued without.onseryationorder___-_-__-_________ No__ ____--_--__-________---------------------------------------_ -- Appr Date 12 Pe[miteanbeissuedwithoutadministrative_approval_______________________- Yes- _--_---__-_-----_-___----_--__-_____--_--__. - - - - RPC 8125!2004 13 Can permit be approved before 15-0ay wait Yes see above 14 Well located within area and strata authorized byJnjection Orde[ # (put1O# in_comments)_(For_ NA_ - The_existing Swanson Rlver gas storage orderwillhave to.beadministratively ammended fo accommodate-KGSF- 15 All wells within 1!4-mile area of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - - _ _ -KGSF 2, KGSF 3, KGSF 7, SRU 43-28, $Rl! 314: ~7- - - - - - - - - - - - - - - - - - - - - _ - - - - - - _ - _ _ _ - _ _ - 16 Pre•produced injector_ duration ofpre-p[oduotion less than 3 months-(For service well only) - NA_ - -- - -- - - 17 ACMP-Finding of Consisteney_hasbeenissuedforthisproject-------------------- NA_- _--_-_-________-----__--___-__--___--___-___-________-____________-_--- Engineering 18 Conductor string-Provided - - - - ~ - - - - - - - - - - - - - - - - - - - - - 19 Surface-casing-protecas all known USDWS - - - ~ - - - - - 20 CMT_vol_adequate-tocirculate_onconductor&surf-csg ........................ NA-_ __-___-_-------_-__---_--__________-_____- --____ 21 CMT_voladequate-totie•inlongstringtosurfOSg___________________________ Yes. _--_-_--_-_____---_-----_-_-___-__---__-________________ -------------- 22 CMT-will coverall knownproductive horizons . . .. . . ....... . . .. . . . . .. . . . . .. Yes . - - - -------------------------------------------------------------------- 23 Casing designs adequatefo[C,TB&_permafrost---- --------------------- Yes- --------------------------------------.------------------------.--.------- 24 Adequate tankage-orreseryepit________________________ _.. Yes- __-___GI_acierRig 1.__--__--_________ 25 Ifa_re-doll,has-a-10-403 for abandonment been approv_ed_______- ------ Yes- -___-_812412004_____________________________________________ ----------------- 26 Adequatewellboreseparatianproposed_________________________________ Yes- .---.-.-.____________----- ----------------------------------------------- 27 Ifdjverterrequired,doesitmeetregulations______-______________________ NA-- _--._Sidetrack.______-___--____-__-__-__--_--__-__----_--_ ------------------ Appr Date 28 Dnllingfluid-program schematic_&equiplistadequate_.___-__.__-_--_____-- Yes- .._-._MaxMW-10A-ppg._____________________________________________-_____- WGA 8126!2004 29 BOPES,dotheymeetregulation________________------_--__--_---_- Yes- ___-______---.-_..__.-_-__-____-_____________---. 30 BOPE_pressratingapp[op[iate;tesfto.(putpsigincomments)-----__--__-___--- Yes_ _-_.-_Testto 3500.psi._MSP2217psi__________________________________________________ 31 Choke_manifold complieswlAPI_RP-53 (M_ay $4) - - Yes - - - - - - - - - - - - - - 32 Work will occur without operation shutdown----------------------- _---- Yes- -------------------------.------------------------------------------ _--- 33 Is presence-of H2S gas probable - - - - - - - - - NO - - - - - - - - - - - - - 34 Mechanical condition of wells within AQR verified (Forsenrice well onlya - _ _ - _ _ NA- - - - - - - - - - - - - - - - - - Geology 35 Pe[mitean be issued wlo. hydrogen_sulfide measures - - - - - - - - - - - - - - - - - - - - - - - Yes - _ ---------------------------------------------------------------- 36 Data_presentedon-potentialoverpressurezones--________-_-_-_---_-- NA__ _________________________________________________ ------------------------ Appr Date 37 Seismic analys~sofshallowgas.zones - --- -- -- -- --- - - ~ - - --- -- - - -- -- -- ---- --------- --- -- -- - RPC 8/2512004 38 Seabedcondjtionsurvey_(ifoffshore)---------------_----__-__-__----- NA__ ____-_- ------------------------------------------------------------------ 39 Contact namelphone for weekly progress_reports [exploratory only]- _ - _ NA- - - _ Geologic Engineering Commissioner: Date: Commissioner: Date C mi er D e DTs $~z61~ ~ D I~ •