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Home My WebLink About207-082Nolan Vlahovich Hilcorp Alaska, LLC Geotech 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: 1/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240107 Well API #PTD #Log Date Log Company Log Type AOGCC Eset # END 2-72 50029237810000 224016 11/16/2024 HALLIBURTON TEMP END 2-74 50029237850000 224024 12/5/2024 HALLIBURTON MFC24 END 2-74 50029237850000 224024 8/13/2024 DarkVision HADES (Down hole camera) KGSF 1A 50133101600100 220063 12/5/2024 HALLIBURTON EPX-MFC40 MPU F-13 50029225490000 195027 12/22/2024 HALLIBURTON WFL-TMD3D PU F-40 50029222150000 191117 11/9/2024 READ CaliperSurvey MPU I-04A 50029220680100 201092 11/22/2024 HALLIBURTON COILFLAG MPU J-02 50029220710000 190096 12/22/2024 READ CaliperSurvey PBU L-04 50029233190000 206120 11/23/2024 HALLIBURTON WFL-TMD3D PBU L-221 50029233850000 208031 12/11/2024 HALLIBURTON WFL-RMT3D PBU Z-ϯϰ 50029234690000 212061 12/15/2024 HALLIBURTON WFL-RMT3D PBU Z-2ϯϱ 50029237600000 223055 9/24/2024 READ InjectionProfile PBU Z-ϮϮϯ 50029237200000 222080 11/24/2024 HALLIBURTON WFL-TMD3D SCU 42-05Y 50133205700000 207082 12/7/2024 HALLIBURTON EPX-MFC24 TBU D-16RD 50733201830100 180110 12/19/2024 READ CaliperSurvey TBU D-17RD 50733201680100 181023 12/21/2024 READ CaliperSurvey Please include current contact information if different from above. T39915 T39916 T39916 T39917 T39918 T39919 T39920 T39921 T39922 T39923 T39924 T39925 T39926 T39927 T39928 T39929 SCU 42-05Y 50133205700000 207082 12/7/2024 HALLIBURTON EPX-MFC24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.07 15:26:55 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, April 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 42-05Y SOLDOTNA CK UNIT 42-05Y Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/17/2023 42-05Y 50-133-20570-00-00 207-082-0 N SPT 7687 2070820 1922 2530 2544 2544 2540 0 0 0 0 4YRTST P Adam Earl 3/16/2023 MIT-IA 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:SOLDOTNA CK UNIT 42-05Y Inspection Date: Tubing OA Packer Depth 244 2116 2104 2098IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230322111926 BBL Pumped:1.2 BBL Returned:1 Monday, April 17, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 999 *DVVWRUDJHLQMHFWRUSURGXFHU 9 9James B. Regg Digitally signed by James B. Regg Date: 2023.04.17 15:46:00 -08'00' MEMORANDUM TO: Jim Reggp 7� P.I. Supervisor '�I �I �1 I l� FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, April 19, 2019 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 42-05Y SOLDOTNA CK UNIT 42-05Y Sre: Inspector Reviewed B P.I. Supry Comm Well Name SOLDOTNA CK UNIT 42-03Y API Well Number 50-133-20570-00-00 Inspector Name: Jeff Jones Permit Number: 207-082-0 Inspection Date: 326/2019 Insp Num: mit1J190403180534 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 4z-osv !,Type N TVD 7687 Tubing Non 2613 o11 2613- _ _ — -- 0 _ PTD zo70820 Type Test sPT Test psi 9zz IA s zoas ' a: oao BBL Pumped: 0.5 - iBBL Returned: 1.2 - OA Interval 4YMT P/F P Notes: This is confirmation of MIT performed 325/19 that was affected by thermal expansion of cold test fluid pumped into a hot well. / Friday, April 19, 2019 Page I of 1 MEMORANDUM TO: Jim Regg �7 P.I. Supervisor �eq 1 �' 74"I t j FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 23, 2019 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 42-05Y SOLDOTNA CK UNIT 42-05Y Sra Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name SOLDOTNA CK UNIT 42-05Y API Well Number 50-133-20570-00-00 Inspector Name: Jeff Jones - Permit Number: 207-082-0 Inspection Date: 3/25/2019 Insp Num: mitJJ190403174233 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well j 42-05Y - Type Inj N TVD 7687 Tubing 2588 25e9 - 89 PTD I 207o820 !Type Test SPT jTest psi 1922 IA 1937 - 1928 - 1923 -� BBL Pumped-] Pumped ] BBL Returned: OA Interval' 4YRTST P/F P Notes Tuesday, April 23, 2019 Page I of I MEMORANDUM TO: Jim Regg '//ll�� P.I. Supervisor ' \"y fm I i FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 23, 2019 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 42-OSY SOLDOTNA CK UNIT 42-05Y Sre: hispector Reviewed By: P.I. Supry Tb2-- NON-CONFIDENTIAL Comm Well Name SOLDOTNA CK UNIT 42-05Y API Well Number 50-133-20570-00-00 Inspector Name: Jeff Jones Permit Number: 207-082-0 Inspection Date: 3/25/2019 Insp Num: mit1n90403171818 Rel Insp Num: Tuesday, April 23, 2019 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 42-OSY - Type Inj N -TVD 7657 "Tubing -'481 2487 1495 1486 PTD 2070820 Type Test SPT Test psi 1922 — IA 1 1943 1947 1951 BBL Pumped: BBL Returned: 2 OA i 1,2t- 1.3 Intervaaaa 4YRTST P/F ✓ Notes: The temperature differential between the 29 degree test fluid and approx. 175 degree well head caused thermal effect preventing proper stabilization. The LA pressure was bled down to 1939 psig and monitored until stabilization criteria achieved. Tuesday, April 23, 2019 Page 1 of 1 MEMORANDUM State of Alaska Permit Number: 207.082-0 Inspection Date: 3/25/2019 ' Alaska Oil and Gas Conservation Commission ' To: Jim Regg 412911 � DATE: Tuesday, April 23, 2019 P.1. Supervisor �G( !!! SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC Packer Depth Pretest Initial 42-05Y FROM: Jeff Jones SOLDOTNA CK UNIT 42-05Y Petroleum Inspector TYPe Inj N JVD Src: Inspector TUbing Reviewed By: r 2495 ' P.I. SuprvJ5rz- NON -CONFIDENTIAL Comm Well Name SOLDOTNA CK UNIT 42-05Y API Well Number 50-133-20570-00-00 Inspector Name: Jeff Jones Permit Number: 207.082-0 Inspection Date: 3/25/2019 ' Insp Num: mitJJ190403170227 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 4z-osv TYPe Inj N JVD 687 TUbing 2610 ' r 2495 ' 2493 - 2486 ' 2486 8Y D 2o7os2L o Type Testi SPT Test psi 1922 IA 233 2126 2146 ' 2163 2172 2183 Pumped: FBB 1.4 BBL Returned: OA 1.1 1 1 1 04 05rval 4YRTSr P/F I ✓ Notes: The temperature differential between the 29 degree test fluid and approx. 175 degree well (read caused thermal effect preventing proper stabilization. There is a slight amount of hydraulic fluid leaking from the tubing hanger void cap; operator will address this item. TIO - 75 Min. 2489/2207/.1, 90 Min. 2488/2211/.4, 105 Min. 2488/2216/.6, 120 Min. 2489/2220/.9 Tuesday, April 23, 2019 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,March 31,2015 TO: Jim Regg Kelej '1� P.I.Supervisor SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 42-05Y FROM: Bob Noble SOLDOTNA CK UNIT 42-05Y Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J 2 NON-CONFIDENTIAL Comm Well Name SOLDOTNA CK UNIT 42-05Y API Well Number 50-133-20570-00-00 Inspector Name: Bob Noble Permit Number: 207-082-0 Inspection Date: 3/23/2015 Insp Num: mitRCN150324092209 Rel lnsp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Type ,- -- _,Well 42-05Y yP G-IITVD 7687 Tubing 2650 2650 2660 ' 2660 -- --—f— PTD' 2070820 'Type Test'SPT'Test psi, 1922 ' IA 1048 2117 ' 2117 2118 ' OA Interval 14—YRTST P/F 1 P / --If 0 0 0 0 - - L ! Notes: _- – — INFO , W At Tuesday,March 31,2015 Page 1 of 1 ~ • XHVZE Image Project Well History File Cover Page 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. ~~ ~- ~ ~ ~ Well History File Identifier - ~ Organizing (done) ^ Two-sided III IIIIII II III (I III ^ Rescan Needed III IIIIII II II III III RE AN DIGITAL DATA OVERSIZED (Scannable) ~ Color Items: ^ Diskettes, No. ^ Maps: ~~reyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: BY: Maria Date: ~ ~ ~ ~S~ Pro'ect Proofin III II~II) IIIII II III J g BY: _ Maria Date: ~ r I~-l ~~ lsl ~~ Scanning Preparation ,~_ x 30 = BY: Maria Date_ ' ' ~ Production Scanning ~ + ~~~C~ = TOTAL PAGES~ ( ount does not include cover sheet) ~~ /s/ Stage 1 Page Count from Scanned File: ~~_ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES ND BY: Maria Date: ~ i c~-/ 0~ /s/ ~ ~~ ~ ~ ~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~S~ I IIIIIIII~ Scanning is complete at this point unless rescanning is required. II~ ~~ ~I I I ReScanned II I() ~I II I( III I I(II BY: Maria Date: ~S~ Comments about this file: Quality Checked II) IIIIII III II~I III 10/6/2005 WeII History File Cover Page.doc • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 07, 2011 2:04 PM %‘1 D o` 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 1 'Ili eg 4\---Wk`k4, • 70.%* 3/7/2011 2010 December's SRF Tyonek 777and Storage Well Monitoring Report • Page 1 of 2 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Monday, January 10, 2011 2:26 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: FW: 2010 December's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report c/ Almost correct Tom. O 0 b X & Y are the active wells in the 77 -3 gas storage sand and 42A -05 & 42B -05 were completed in the same sand, but have since both been suspended. Both A & B are being used as monitoring wells in case the gas gets out of the 77 -3, but neither has open perfs in that sand today. It is true that there are a number of other wells we are using to monitor the storage reservoir that penetrate, but were never completed in the 77 -3 sand. I do believe the split of the gas storage pool code for the 64 -5 & 77 -3 sands will be forthcoming from production accounting. They truly are separate accumulations, but both Tyonek sands. Let me know if you need more info. Larry k `( ‘t From: Maun er, omas ) [mailto:tom.maunder @alaska.gov] Sent: Monday, January 10, 2011 1:55 PM To: Greenstein, Larry P; Regg, James B (DOA) Cc: Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: RE: 2010 December's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Larry, et al, I have been working with McMains sorting out the Swanson River storage gas. The two Swanson storage projects employ Tyonek reservoirs (64 -5 and 77 -3), but they are separate accumulations. From a reporting sense, all the volumes had been being reported under one pool code. I think that has been changed or is in the process of being changed. The question I have regards 77 -3 storage. As I understand, 42 -05X and 42 -05Y are the active injection /production wells. 42 -B -05 and 42A -05 are completed in the 77 -3 sand, but are not being actively employed. There are a number of wells that penetrate the sand enroute to the Hemlock, but none are completed in the 77 -3 sand. Do I have that correct? Thanks in advance, Tom Maunder, PE AOGCC From: Greenstein, Larry P [mailto :Greensteinlp @chevron.com] Sent: Monday, January 10, 2011 9:29 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Ayer, Phil M; Walsh, Chantal [ Petrotechnical Resources of Alaska (PRA)] Subject: 2010 December's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Hi Jim & Tom, Here is December's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77 -3 Sand Storage reservoir. 3/11/2011 2010 December's SRF Tyonek land Storage Well Monitoring Report Page 2 of 2 Both X & Y are in heavy usage now that the winter is in full swing, but the warmth at the end of December did allow a little injection to occur. While performing the MIT on 5X last month the operators noted that leaving the annulus with 0 pressure readings didn't offer much to monitor. They put a few hundred psi on both the 5X & 5Y well 7" annulus to better monitor pressure changes. Both annuli are now showing some ups and downs related to temperature swings based on injection vs production at different rates. Neither annulus appears to be tracking or communicating with the tubing pressures, they are just much more responsive now that there is some pressure on them to observe. The pressure responses from both wells were within expectations with no indications of any loss of integrity. Bottom line, the pressures for all the monitored wells remain within their expected ranges. Larry «Master Well List TIO Report 2011 01 01.xIs» p S v � 1 Nr ., 3/11/2011 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission / DATE: Tuesday, August 23, 2011 TO: Jim Regg ) C/ q I , P.I. Supervisor SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 42-05Y FROM: Jeff Jones SOLDOTNA CK UNIT 42 -05Y Petroleum Inspector Src: Inspector Reviewed By P.I. Supry �35, NON - CONFIDENTIAL Comm Well Name: SOLDOTNA CK UNIT 42 - 05Y API Well Number: 50 133 - 20570 - 00 - 00 Inspector Name: JeffJones Insp Num: mitJJ110818130118 Permit Number: 207 - 082 - Inspection Date: 8/16/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 42 -0 5Y ' T ype Inj. G ` TVD ? 7687 T IA I 14 2200 2182 2175 ' P.T.D 2070820 ,TypeTest S Test psi 1921 - OA _ 0 0 0 0 1 Interval 4YRTST - P/F P - Tubing 4552 4553 4550 4552 Notes: 1.5 BBLS diesel pumped. 1 well inspected; no exceptions noted. • Tuesday, August 23, 2011 Page 1 of 1 • • Well Name: SCU 42-05Y Operator: Union Oil Company of California Field: Swanson River Unit: Soidotna Creek API: 50-133-20570-00 Pemtit: 207-082 Well Status: !Gas Storage RKB: 16.77' above GL .____I L TO/TIM: 18,110 MD/8,042' WO IPBTD/PBTVD: 18014' (drilled ant to float collar) Casing Detail Size Wt Grade (Type Top (FT) Btrn (FT) Length (FT) 16" 109# K-55 OM 96 96 9-5/8" 47# 1-89 BTC 0.00 3,054 3,054 7. 26# 1-80 TC-2 0.00 8,097 8,097 Tubing Detail Size Wt I Grade Type I Top (FT) Btm (FT) Length (FT) i 3-1/2" 9.2# 1-80 Atlas Bradford TC-2 0.00 7,809 7,809 Jewelry Detail 1 Chemical Injection Mandrel (with Improved Modified Buttress connections) 2,498 2 HES Sliding Sleeve 7,706 3 B07' SAB-3 Perm. Packer with a K-Anchor and MAI out extension 7,754 4 XN-Nipple (275") 7,800 = 2 5 3-1/2" Ported Sub 7,808 6 3-1/2" IBT joint 7,809 7 3-1/2" release (Halriburton Automatic Release Assy.) 7,841 Z 3 E 9 Top of Dropped TCP Assy. (28' long) 8,069'1 ::,, ' - ' 4 0 0 5 Perforation Detail 7 6 Zone SPF Date Top (FT) Min (FT) Length (FT) \ 77-3 5 8/28/2007 7,846.00 7,864.00 18' 1 --= =-___-- -=-_ 0 • 9 !Last Revisprl I CIP7IPNY17 1 2011 May's SRF Tyonek 77 -3 Sanorage Well Monitoring Report Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Monday, June 06, 2011 2:10 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: 2011 May's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Attachments: Master Well List TIO Report 2011 06 01.xis Hi Jim &Tom, DCs 1— Th Here is May's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77 -3 Sand Gas Storage reservoir. The storage wells are in full injection cycle now and the tubing pressures are climbing as expected. Some of the offset producers (like SCU 12A -04 & SCU 332 -04) have pressures that move around, but nothing related to the change in use of the storage wells. Once again, the 77 -3 sand monitoring wells appear to show no indications of a loss of storage gas containment. Larry «Master Well List TIO Report 2011 06 01.xis» JUN 0 6 201; 6/6/2011 Plot Pressure & Rate vs Time - Well SCU 42 -05Y • 5000 - - 20000 — 7" � 9 5/8" 4500 • Tubing -- - - 18000 • Vol Inj • Vol Prod 4000 16000 3500 4,, - / 14000 3000 _ _ -- -- 2500 y 1200° 1000 ✓ 1I cu I 2000 -. I - 8000 1500 I — 1 i I -- 6000 li , ' 1000 l 1 Ift - -- 4000 500 n . -� � I , ��, ;lin 2000 0 II 0 O O h M O M M M Lo O O O O O Date 7" §" ny vol' void TIO Report 06/01/11 200 0 3756 12024 0 1 05/31/11 200 0 3623 10339 Data Sheet 05/30/11 200 0 3626 11778 05/29/11 200 0 3569 11941 05/28/11 150 0 3468 9035 SCU 42 -05Y 05/27/11 140 0 3323 3402 I 05/26/11 100 0 3468 10086 05/25/11 100 0 3481 12497 INJECTION 05/24/11 00 0 3429 14764 0 05/23/11 00 0 3269 10924 0 05/22/11 100 0 3438 16732 0 Permit # 2070820 05/21/11 100 0 3221 14119 0 05/20/11 _ 100 0 3175 13427 0 05/19/11 - 105 0 3073 11264 0 API # 50 -133- 20570 -00 05/1 8/11 - 100 0 3020 12662 0 05/17/11 110 0 2984 12671 05/16/11 100 0 2814 11689 12/01 /2010 to 06/01 /2011 05/15/11 100 0 2814 8351 05/14/11 100 0 2761 10289 05/13/11 100 0 2916 13037 05/12/11 ' ' 0 2056 15118 05/11/11 100 0 2659 9792 05/10/11 100 0 2565 10066 0 05/09/11 100 0 2516 9238 0 05/08/11 100 0 2554 11544 0 05/07/11 100 0 2481 10221 0 05/06/11 100 0 2424 10138 0 05/05/11 100 0 2248 5945 0 05/04/11 • 100 0 2224 5644 0 05/03/11 100 0 2191 4945 0 05/02/11 100 0 2080 0 0 05/01/11 140 0 2051 1769 0 04/30/11 140 0 2129 5576 04/29/11 140 0 2131 4310 04/28/11 140 0 2076 4845 04/27/11 140 0 2021 2776 6/6/2011 2:53 PM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 06 01.xIs SCU 42 -05Y 2011 April's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report • Page 1 of 1 • Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Tuesday, May 10, 2011 4:13 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: 2011 April's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Attachments: Master Well List TIO Report 2011 04 30.xls Hi Jim & Tom, 2.0 ;0� -0�sD- Y,,F. y Here is April's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77 -3 Sand Gas Storage reservoir. The storage wells are now getting some gas back into the ground and the tubing pressures have started to climb as expected. Some of the offset producers (like SCU 12A -04 & SCU 332 -04) have pressures that move around, but nothing related to the change in use of the storage wells. The SCU 42A -05 well appears to have settled down lately, maybe it was the long freeze / thaw kind of spring that had this suspended well's pressures moving so much. All in all, the 77 -3 sand monitoring wells appear to show no indications of a loss of storage gas containment. Larry «Master Well List TIO Report 2011 04 30.xls» 5/16/2011 w Plot Praire & Rate vs Time - Well SCU 42 -05Y1 4000 18000 3500 I I 16000 — 7• I •""""•9 5/8" •3000 Tubing 14000 Vol Inj —. I I •Vol Prod ! , 12000 2500 — — E II, i I u 00 I V , 10 a 2000 1 8000 1500 i __ ii i 1 1 6000 1000 — FM 4000 I , 500 n 1 I i • I I �� I 2000 0 I\ I '' 1 0 0 0 0 _ _ o rn rn m a m M N N N N N N ■ 0 N N M V O O O O Date S/8" - Tubin' Vol lnj Voles' TIO Report 04/30/11 140 0 2129 5576 04/29/11 140 0 2131 4310 Data Sheet 04/28/11 140 0 2076 4845 04/27/11 140 0 2021 2776 04/26/11 140 0 2110 10160 0 SCU 42 -05Y 04/25/11 0 350 1904 8500 0 04/24/11 140 0 1823 2163 0 04/23/11 120 0 1853 2678 0 INJECTION 04/22/11 120 0 1959 8459 0 04/21/11 115 0 1794 7375 0 04/20/11 125 0 1750 4769 Permit # 2070820 04/19/11 150 0 1601 5765 327 04/18/11 150 0 1590 2211 04/17/11 150 0 1660 0 API # 50- 133 - 20570 -00 04/16/11 150 0 1913 8460 04/15/11 150 0 1600 4656 04/14/11 150 r, 0 1554 2826 10/30/2010 to 04/30/2011 04/13/11 0 1566 5208 04/12/11 ' ' + ! 0 1424 2382 0 04/11/11 150 0 1426 4561 04/10/11 65 0 1315 866 0 04/09/11 '60 0 1280 0 0 04/08/11 ' 80 0 1181 0 5416 04/07/11 ` 380 0 1024 0 8222 04/06/11 390 0 1119 0 6744 04/05/11 400 0 1085 6464 04/04/11 400 0 1076 0 6036 04/03/11 350 0 1146 4567 04/02/11 0 1075 6533 04/01/11 0 1151 0 7080 03/31/11 400 ` 0 1229 0 6083 03/30/11 425 0 1285 0 3493 03/29/11 425 0 1124 0 6762 03/28/11 ' ' r . 0 1113 0 7025 03/27/11 0 1135 0 7997 03/26/11 0 1160 0 7474 5/16/2011 11:13 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 04 30 (4).xls SCU 42 -05Y 2009 August's SRF Tyonek 77 -3 S,Storage Well Monitoring Report Page 1 of IA Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Tuesday, September 15, 2009 7:19 AM To: Maunder, Thomas E (DOA) Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Sounds good Tom, I'll find a way to get this done...hopefully with the correct axis label, but if not, some kind of side note. Thanks , j1 —� Larry _.— '' b� — g 6� From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, September 14, 2009 9:14 PM To: Greenstein, Larry P Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report If you can't, thats OK. The storage wells are the only ones where you all inject gas. You might just make a note in the "note field" where you give the specifics on the well. Tom From: Greenstein, Larry P [mailto :Greensteinlp @chevron.com] Sent: Mon 9/14/2009 5:23 PM To: Winslow, Paul M; Maunder, Thomas E (DOA) Cc: Ayer, Phil M; Regg, James B (DOA) Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Thanks Paul. Tom, I'll look into the program that spits out these plots to see if we can tweak it to be more accurate on the labeling. Larry Fro inslow, Paul M Sent: Mon • . September 14, 2009 4:15 PM To: Maunder, Tho ; E (DOA); Greenstein, Larry P Cc: Ayer, Phil M; Regg, • - s B (DOA) Subject: RE: 2009 August's S' - onek 77 -3 Sand Storage Well Monitoring R- • Tom, Prior to April 2009, we had only injected int. -s5X, and ha. • • • uced from both 42 -05X and 42 -05Y. After installing a coalescer this year, we s . - • injecting into both 42 -05Y a : 12-05X. From here on out, we will be injecting and producing fro.. .oth wells. Paul 3/7/2011 L MY 'August. s ,Jrcr 1yoiex i r -J 3a1K1 3lorage w ivanmoring Iceporl rage 1 01 G • • Maunder, Thomas E (DOA) From: Winslow, Paul M [PWinslow @chevron.com] Sent: Monday, September 14, 2009 4:15 PM To: Maunder, Thomas E (DOA); Greenstein, Larry P Cc: Ayer, Phil M; Regg, James B (DOA) Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Tom, Prior to April 2009, we had only injected into 42 -05X, and had produced from both 42 -05X and 42 -05Y. After installing a coalescer this year, we started injecting into both 42 -05Y and 42 -05X. From here on out, we will be injecting and producing from both wells. Paul Paul Winslow Chevron North American Exploration & Production MidContinent / Alaska Business Unit 3800 Centerpoint Dr., Suite 100, Anchorage, AK 99503 Tel: 907- 263 -7629 Cell: 907 - 382 -3813 Fax 907 - 263 -7828 pwinslow @chevron.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, September 14, 2009 3:59 PM To: Greenstein, Larry P Cc: Ayer, Phil M; Winslow, Paul M; Regg, James B (DOA) Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Hi Larry, et al, It will be interesting to see the pressure plot next month on 12A -04. On 5X and 5Y, there are a couple of items, One is listed as an injection well and the other a storage well_ Do both wells inject gas and then produce it back? In our data base they are both listed as "GSTOR ". Also, the volume on the right axis says BBLS. Should that be MCF? Thanks in advance. Tom Maunder, PE AOGCC From: Greenstein, Larry P [ mailto :Greensteinlp @chevron.com] Sent: Monday, September 14, 2009 2:44 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Ayer, Phil M; Winslow, Paul M Subject: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Hi Jim & Tom, Here is August's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77 -3 Sand Storage reservoir. 9/14/2009 2009 August's SKI' 'lyonek 77 -3 Sand Storage Well Monitonng Report Page 2 of 2 • We are still injecting into the wells, but the volumes are slowing down as the reservoir fills up. Both the 5X & 5Y wells are getting gas injected and the tubing pressures show the increases expected. The 12A-04 well WO has been completed and production has started, it is having some problems, but we are still trying to clean up the lost fluids and get production rates up. The rest of the wells appear to have pressures for the month that don't show any indications of a response due to the gas storage operations. Bottom line, the pressures remain in expected ranges for all the wells being monitored. Larry «Master Well List TIO Report 2009 09 01.xis» 9/14/2009 f Plot Prere & Rate vs Time - Well SCU 42 -05X • 4500 ' _._..- F 14000 4000 - - - 7 •9 5/8" 12000 •Tubing 3500 - - ___ Vol Prod ••••••` Vol i J . 10000 3000 cu 2500 8000) N m d m a` 2000. N°' k. 6000 1500 1 4000 1000 t - - - -- _ ... \tot---- ..__._- 2000 500 ..■■•••■ P_.■■• rn $ rn rn . O Q o o o o o N m O O O M CO M N O O O O O O co Date 7" 9 5 /8" TIO Report 09/01 /09 300 0 - 6 3 08/31/09 300 0 4334 0 177 Data Sheet 08/30/09 300 0 4373 0 1 08/29/09 300 0 4373 0 1 08/28/09 300 0 4396 o 1 SCU 42 -05X 08/27/09 300 0 4388 0 2 08/26/09 320 0 4393 0 1 08/25/09 320 0 4415 0 2607 STORAGE WELL 08/24/09 300 0 4414 0 2682 08/23/09 300 0 4393 0 2763 08/22/09 300 0 4393 0 3021 Permit # 2060740 08/21/09 300 0 4386 0 2220 08/20/09 300 0 4405 0 2557 08/19/09 300 0 4391 0 2771 API # 50- 133 - 20561 -00 08/18/09 300 0 4389 2820 08/17/09 300 0 4395 2751 08/16/09 300 0 4385 2649 03/02/2009 to 09/01/2009 08/15/09 300 0 4388 2664 08/14/09 320 0 4393 0 3122 08/13/09 320 0 4379 0 2675 08/12/09 300 0 4370 2378 08/11/09 300 0 4380 0 2328 08/10/09 300 0 4383 0 2616 08/09/09 300 0 4379 0 2392 08/08/09 300 0 4419 0 08/07/09 300 0 4409 0 08/06/09 300 0 4396 0 3 08/05/09 310 0 4409 0 3957 08/04/09 300 0 4375 0 3921 08/03/09 300 0 4358 0 3312 08/02/09 300 0 4366 0 3830 08/01/09 300 0 4368 0 4428 07/31/09 300 0 4319 0 3358 07/30/09 300 0 4271 0 2009 07/29/09 305 0 4279 0 2310 07/28/09 320 0 4281 0 2099 3/7/2011 4:22 PM - TIO Reports 7e xis J J Dolan Master Well List TIO Report 2009 09 01.xIs SCU 42 -05X Plot Pr•re & Rate vs Time - Well SCU 42 - 05Y• ,._ — ._...._ .: 4500 4500 4000 -- 7 — — — — - - -- -- 4000 � 9 5 /8" ` • Tubing N. 3500 -- --- •VoI Prod • Vol Inj_,_.1 3500 1 3000 ._._.. — 3000 IF.2500 .1 250E d CO O. 2000 — — 2000 1500 —_._ ■ — — ikt —. 1 ■ --- 1500 1000 1000 500 1 :°° 0 1\ — 0 0 0 0 0 0 N O O 0 O O O c7 `§9 c` O O O O O O 0 Date 7" -._— u Volnj' TIO Report 09/01/09 -100 0 4 16 08/31/09 00 0 4343 0 Data Sheet 08/30/09 00 0 4369 0 1 08/29/09 100 0 4363 0 08/28/09 100 0 4386 0 1075 SCU 42 -05Y 08/27/09 100 0 4383 0 1367 08/26/09 100 0 4389 0 1225 08/25/09 100 0 4408 0 1852 INJECTION 08/24/09 100 0 4411 0 1919 08/23/09 100 0 4395 0 2096 08/22/09 100 0 4390 0 2402 Permit # 2070820 08/21/09 - 100 0 4378 0 1351 08/20/09 00 0 4400 0 1608 08/19/09 : 100 0 4389 0 1973 API # 50- 133 - 20570 -00 08/18/09 100 0 4391 2109 08/17/09 100 0 4391 1987 08/16/09 ' .100 0 4381 1882 03/02/2009 to 09/01/2009 08/15/09 00 0 4384 1839 08/14/09 00 0 4391 2600 08/13/09 00 0 4374 0 2082 08/12/09 100 0 4366 1673 08/11 /09 00 0 4374 0 1857 08/10/09 ' 00 0 4378 0 2345 08/09/09 100 0 4378 0 1951 08/08/09 100 0 4416 0 2844 08/07/09 100 0 4401 0 3388 08/06/09 00 0 4391 0 3241 08/05/09 100 0 4405 0 4012 08/04/09 : 100 0 4374 0 3981 08/03/09 ' 100 0 4354 0 3298 08/02/09 100 0 4364 0 3871 08/01/09 - 100 0 4363 0 4719 07/31 /09 100 0 4319 0 3475 07/30/09 100 0 4269 0 1482 07/29/09 100 0 4284 0 1915 07/28/09 1 QQ_.,_, ._.Q.. 4283 0 1676 3/7/2011 4:23 PM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2009 09 01.xIs SCU 42 -05Y c) Summary by Month: Individual Well Storage Well Name: SOLDOTNA CI( UNIT 42-05X API: 50 -133- 20561 -00 -00 Permit to Drill: 2060740 Operator: UNION OIL CO OF CALIFORNIA Field/Pool: SWANSON RIVER, TYONEK GAS ST Sales Cd: 70 Acct Grp: 1 Final Status: GSTOR Current Status: GSTOR 2006 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Shut -In Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Days 0 30 30 27 14 26 Oil 0 0 0 0 0 0 Gas 0 331,869 422,802 110,657 83,366 200,905 2006 Totals: Oil 0 Gas 1,149,599 Cum Oil 0 Cum Gas 1,149,599 2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Shut -In Gas Sto Days 21 17 10 29 21 18 13 31 8 10 0 3 0 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Gas 156,326 106,193 54,252 247,449 74,062 82,060 39,731 139 134,187 41,803 0 19,505 2007 Totals: Oil 0 Gas 955,707 Cum Oil 0 Cum Gas 2,105,306 2008 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Days 3 11 17 30 31 30 31 31 28 23 1 1 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Gas 3,691 117,547 239,096 223,992 212,951 117,095 75,423 44,900 24,393 9,943 1,267 716 2008 1,071,014 Cum Oil 0 Cum Gas 3,176,320 8 1 Totals: Oil 0 Gas ,0 71, 2009 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Days 9 14 1 9 31 30 31 Oil 0 0 0 0 0 0 0 Gas 96,694 80,773 1,687 66,627 348,664 162,392 89,080 2009 Totals: Oil 0 Gas 845,917 Cum Oil 0 Cum Gas 4,022,237 I Monday, September 14, 2009 Page 1 Summary by Month: Individual Well Production Well Name: SOLDOTNA CK UNIT 42 -05X API: 50- 133 - 20561 -00 -00 Permit to Drill: 2060740 Operator: UNION OIL CO OF CALIFORNIA Field/Pool: SWANSON RIVER, TYONEK GAS ST Sales Cd: 70 Acct Grp: 1 Final Status: GSTOR Current Status: GSTOR 2006 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Flowing Flowing Shut -In Shut -In Flowing Flowing Days 7 2 0 0 1 3 Oil 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 Gas 35,263 6,215 0 0 66,196 • 12,889 2006 Totals: Oil 0 Water 0 Gas 120,563 Cum Oil 0 Cum Wtr 0 Cum Gas 120,563 2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Flowing Flowing Flowing Shut -In Shut -In Shut -In Flowing Shut -In Shut -In Flowing Flowing Flowing • Days 10 9 10 0 0 0 1 0 0 20 4 22 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 0 0 0 0 0 0 Gas 70,834 56,748 88,933 0 0 0 103 0 0 64 29,621 171,247 2007 Totals: Oil 0 Water 0 Gas 417,550 Cum Oil 0 Cum Wtr 0 Cum Gas 538,113 2008 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Flowing Flowing Flowing Flowing Flowing Shut -In Shut -In Shut -In Flowing Flowing Flowing Flowing Days 26 20 29 17 31 0 0 0 5 1 18 27 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 0 0 0 0 0 0 Gas 227,468 120,442 24,957 12,168 414 0 0 0 448 47,208 222,108 223,913 2008 Totals: Oil 0 Water 0 Gas 879,126 Cum Oil 0 Cum Wtr 0 Cum Gas 1,417,239 2009 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec • Meth Flowing Flowing Flowing Flowing Shut -In Shut -In Shut -In Days 29 14 21 7 0 0 0 Oil 0 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 0 Gas 127,939 89,080 46,556 59 0 0 0 2009 Totals: Oil 0 Water 0 Gas 263,634 Cum Oil 0 Cum Wtr 0 Cum Gas 1,680,873 Monday, September 14, 2009 Page 1 Summary by Month: Individual Well Production Well Name: SOLDOTNA CK UNIT 42 -05Y API: 50 -133- 20570 -00 -00 Permit to Drill: 2070820 Operator: UNION OIL CO OF CALIFORNIA Field/Pool: SWANSON RIVER, TYONEK GAS ST Sales Cd: 70 Acct Grp: 1 Final Status: GSTOR Current Status: GSTOR 2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Flowing Flowing Shut -In Shut -In Flowing Days 4 30 0 0 8 Oil 0 0 0 0 0 Wtr 0 0 0 0 0 Gas 18,925 35,500 0 0 35,047 2007 Totals: Oil 0 Water 0 Gas 89,472 Cum Oil 0 Cum Wtr 0 Cum Gas 89,472 2008 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Flowing Flowing Flowing Flowing Shut -In Shut -In Shut -In Shut -In Shut -In Flowing Flowing Flowing Days 27 16 31 30 0 0 0 0 0 9 11 27 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 0 0 0 0 0 0 Gas 228,082 180,632 5,280 5,255 0 0 0 0 0 80,068 94,718 312,349 2008 Totals: Oil 0 Water 0 Gas 906,384 Cum Oil 0 Cum Wtr 0 Cum Gas 995,856 2009 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Flowing Flowing Flowing Flowing Shut -In Shut -In Shut -In Days 14 13 21 7 0 0 0 Oil 0 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 0 Gas 182,169 132,598 92,950 570 0 0 0 2009 Totals: Oil 0 Water 0 Gas 408,287 Cum Oil 0 Cum Wtr 0 Cum Gas 1,404,143 • Monday, September 14, 2009 Page 1 1 Summary by Month: Individual Well Storage Well Name: SOLDOTNA CK UNIT 42 -05Y API: 50 -133- 20570 -00 -00 Permit to Drill: 2070820 Operator: UNION OIL CO OF CALIFORNIA Field/Pool: SWANSON RIVER, TYONEK GAS ST Sales Cd: 70 Acct Grp: 1 Final Status: GSTOR Current Status: GSTOR 2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Shut -In Shut -In Shut -In Shut -In Shut -In Days 0 0 0 0 0 Oil 0 0 0 0 0 Gas 0 0 0 0 0 2007 Totals: Oil 0 Gas 0 Cum Oil 0 Cum Gas 0 2008 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Shut -In Shut -In Shut -In Shut -In Shut -In Shut -In Shut -In Shut -In Shut -In Shut -In Shut -In Shut -In Days 0 0 0 0 0 0 0 0 0 0 0 0 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Gas 0 0 0 0 0 0 0 0 0 0 0 0 2008 Totals: Oil 0 Gas 0 Cum Oil 0 Cum Gas 0 2009 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Shut -In Shut -In Shut -In Gas Sto Gas Sto Gas Sto Gas Sto Days 0 0 0 1 31 30 31 Oil 0 0 0 0 0 0 0 Gas 0 0 0 4,052 383,772 188,982 84,826 2009 Totals: Oil 0 Gas 661,632 Cum Oil 0 Cum Gas 661,632 • I Monday, September 14, 2009 Page 1 r.. Chevron Petroleum Winslow Chevron North America Petroleum Engineer Advisor Exploration and Production r ..` MidContinent/Alaska SBU 3800 Centerpoint Dr., Ste 100 J Anchorage, AK 99503 Tel (907) 263 -7629 Email pwinslow @chevron.com .71\ lr lJ t February 23, 2009 FEB ' 2009 Mr. Dan Seamount, Chairman ; OIL 1 Alaska Oil and Gas Conservation Commission 333 W. 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Annual Material Balance Calculations of Production and Injection Volumes Swanson River Gas Storage Facility #3 (Tyonek 77 -3 sand) (Z) Swanson River Field l Qcc Dear Commissioner Seamount: Attached for your review is the annual material balance calculation of production and injection volumes for the Swanson River Gas Storage Facility #3 (SRGSF #3), as required per AOGCC Storage Injection Order #6 (SIO #6). SRGSF #3 applies to the Tyonek 77 -3 reservoir, which has had four wells completed in it.4SCIJ 42A -05. SCU 42B -05. SCU 42 -05X. and SCU 42 -05Y). This material balance report covers the primary production period, as well as the gas storage operations that have taken place from October 1, 2005 to the present time. Attachment #1 is a table of gas production and injection volumes for the SCU 42A -05, SCU 42B -05, SCU 42 -05X, and SCU 42 -05Y wells, from the commencement of primary production (July 2004) up through February 22, 2008. Note that the January and February 2009 volumes are estimated from daily metered values. Historic reservoir pressure estimates have been obtained primarily through surface shut -in tubing pressure (SITP) readings which were then converted to bottomhole pressures. In addition to the SITP's, downhole pressure gauges have been run several times, to obtain static bottomhole pressures and /or to conduct pressure transient tests. These data points are tabulated in Attachment #2 and plotted versus the corresponding net cumulative production on the standard P/Z plot (Attachment #3). Viewing Attachment #3, it has previously been noted that the early injection cycle pressures deviate above the straight line path established from the primary depletion points. Previous Annual Performance Reports have also documented that the production volumes /pressures have deviated below the primary depletion path. The latest 2008 injection and 2008/2009 production cycles mimicked the previously established trends, indicating the continued reservoir confinement of the gas storage volumes. During the peak of the 2007/2008 winter production season (Nov. '07 — Feb. '08), a net total of 852 MMcf of gas was produced from the 77 -3 reservoir. From Mar. - Sep. '08, a net total of 889 MMcf of gas was injected back into storage, via the SCU 42 -05X wellbore. To date (2/23/09) a total of 1,322 MMcf of gas has been withdrawn from storage during the 2008/2009 winter season. Note that after the extended cold period which lasted until mid January, Chevron was MidContinent /Alaska SBU /Chevron North America Exploration and Production www.chevron.com • • Swanson River Gas Storage Facility #3 2008 Annual Performance Report Page 2 able to re- inject a small amount of gas for about a week in mid January (15 — 23 and again in mid February (13 — 20 This injection and offsetting production over the past two months, accounts for the final P/Z vs. cumulative production point seen on Attachment #3. If you have any questions regarding this annual performance report, please contact Paul Winslow at your earliest convenience. Sincerely, 2,1n‘1/421, Paul M. Winslow Petroleum Engineer Advisor Cc: Dave Whitacre Attachments Union Oil Company of California / A Chevron Company http: / /www.chevron.com • • ATTACHMENT #1 SRGSF #3 - PRODUCTION AND INJECTION VOLUMES (TYONEK 77 -3 SAND) 42a -05 42b -05 r 42 -05X 42 -05Y • Tvonek 77 -3 Sand Totals Corn Depletion Inventory Monthly Monthly Monthly Monthly '' Monthly Monthly ! Monthly Monthly • (Prod -Inj) (Primary- Dept Vol) Gas Gas Gas Gas Gas Gas Gas Gas Cum for POZ Total Gas Date Inj Prod Inj Prod Inj Prod lnj Prod • Plotting Inventory MCF MCF MCF MCF MCF MCF MCF MCF MCF MCF Jun -04 0 0 2 ,tV CS Jul -04 0 55,040. 55,040 2,321,960 Aug -04 0 194,185. 249,225 2,127,775 Sep -04 0 173,352 422,577 1,954,423 Oct -04 0 151,770 ` 574,347 1,802,653 Nov -04 0 161,949 736,296 1,640,704 Dec -04 0 116,582 r 852,878 1,524,122 Jan -05 0 160,730 ` 1,013,608 1,363,392 Feb -05 0 160,235 1,173,843 1,203,157 Mar -05 0 164,902 1,338,745 1,038,255 . Apr -05 0 156,158 ' 1,494,903 882,097 May -05 0 172,327' 1,667,230 709,770 Jun -05 0 162,359: 1,829,589 547,411 Jul -05 0 157,953. 1,987,542 389,458 Aug -05 0 114,531 - 2,102,073 274,927 Sep -05 0 71,034 2,173,107 203,893 Oct -05 0 113,342 • 0 2,286,449 90,551 Nov -05 0 53,196 0 20,267, 2,359,912 17,088 a \91 Dec -05 0 0 224,142 16,950' 2,152,720 224,280 ` 1 � Jan -06 0 31,872 22,827 433, 2,162,198 214,802 Feb -06 0 17,334 • 172 0 ; . . . 2,179,360 197,640 Mar -06 0 87,263 24,813 99,300 ; 2,341,110 35,890 Apr -06 0 30,355 0 106,863 ! • 2,478,328 -101,328 May -06 0 0 . 311,189 8; . 2,167,147 209,853 Jun -06 0 0 12,011 0' 2,155,136 221,864 Jul -06 0 863' 0 0• 0 35,2631 2,191,262 185,738 Aug -06 0 131 • 0 0 , 6,215 1,865,739 511,261 Sep -06 0 0 0 0 422,802 0 • F 1,442,937 934,063 Oct -06 110,657 0 1,332,280 1,044,720 Nov -06 83,366 66,196! � 1,315,110 1,061,890 Dec -06 200,905 12,889 • 1,127,094 1,249,906 Jan -07 156,326 70,8341 1,041,602 1,335,398 Feb -07 106,193 56,748 i 992,157 1,384,843 Mar -07 54,252 88,933' 1,026,838 1,350,162 Apr -07 247,449 0! 779,389 1,597,611 May -07 74,062 0' , ' 705,327 1,671,673 Jun -07 82,060 0' 623,267 1,753,733 Jul -07 39,731 103.` �' 583,639 1,793,361 Aug -07 139 0, 0 18,925E 602,425 1,774,575 Sep 07 134,187 0i ' 0 35,500♦ 503,738 1,873,262 Oct -07 41,803 64 i 0 0'" 461,999 1,915,001 Nov -07 0 29,621 0 0E 491,620 1,885,380 Dec -07 19,505 171,247 0 35,047 ' 678,409 1,698,591 Jan -08 3,691 227,468 !. 0 228,082 f 1,130,268 1,246,732 Feb -08 117,547 120,442 0 180,632 1,313,795 1,063,205 Mar -08 239,096 24,957E 0 5,28011: 1,104,936 1,272,064 Apr -08 223,992 12,168 ` 0 5,2551.,' • 898,367 1,478,633 May -08 212,951 41 4' 0 0( 685,830 1,691,170 Jun -08 • 117,095 OF 0 0(' 568,735 1,808,265 Jul -08 • 75,423 0' 0 0 493,312 1,883,688 Aug -08 44,900 01 0 0 448,412 1,928,588 Sep -08 • 24,393 4480 0 0 424,467 1,952,533 Oct -08 9,943 47,208 r 0 80,068, 541,800 1,835,200 Nov -08 1,267 222,108 ' 0 94,718 857,359 1,519,641 Dec -08 716 223,913 I - 0 312,349 ' 1,392,905 984,095 Jan -09 90,992 127,887 0 182,1251: 1,611,925 765,075 Feb -09 69,655 76,719 , 0 127,244 1,746,233 630,767 January and February (thru 2/22) '09 volumes are estimated from daily metered figures 2/23/2009 0:\ NAU \MCBUWlaska\Depts\AssetDev\CIGas \Gas CFT\Openmind \Swanson \Soldotna Creek Unit North \SCU42A -5\ Surveys 1Pressure'AOGCC 0 • ATTACHMENT #2 SRGSF #3 - P/Z VS. CUM PRODUCTION DATA (Tyonek 77 -3 Sand) Parameter Value Units Gas Gravity 0.563 Bench Datum 7811 ft (tvd) Datum Temp. 141 ° F Datum Temp. 601 ° R Initial Z Guess 0.88 - - Gauge Test Measured Datum Duration Test Depth Pressure at Pressure, Wellname Date Test Type (hrs) (MTD), ft MTD, psis Z Factor Psia Cum Gas, bcf P /Z, Psia Primary Production 42A -5 06/27/04 Surf PBU 1 0 3994 0.9803 4774 0.0000 4870 42A -5 10/22/04 Surf PBU 1 0 3050 0.9110 3646 0.5354 4002 42A -5 12/21/04 BHP Static 1 7982 3194 0.8933 3194 0.8403 3576 42A -5 2/8/2005 BHP PBU 8 7982 2482(SITP) 0.8859 2926 1.0599 3303 42A -5 06/23/05 BHP PBU 8 7811 1985 0.8835 1985 1.7931 2247 42A -5 07/11/05 SITP 2 0 1565 0.8859 1871 1.8881 2112 42A -5 08/25/05 SITP 3 0 1385 0.8923 1655 2.1024 1855 42A -5 09/13/05 _SITP 3 0 1490 0.8883 1781 2.1051 2005 42A -5 10/25/05 BHP PBU 8 7811 1556 0.8959 1556 2.2666 1737 2005 Injection Cycle 142A &B -5 1 1/4/2006 1BHP Static 142 17811 11857 1 0.8803 1 2232 1 2.1423 1 2536 2006 Production Cycle 42A &B -5 3/10/2006 SITP 4 0 1895 0.8802 2236 2.1633 2540 42A &B -5 3/18/2006 BHP Static 1 7811 2026 0.8827 2026 2.2260 2295 42B -5 4/12/2006 BHP Static 42a- 120 0 1412 0.8911 1689 2.4038 1895 42B -5 5/4/2006 SITP 96 0 1280 0.8969 1530 2.4783 1706 2006 -2007 Injection Cycle 42A &B -5 5/17/2006 SITP 48 0 1528 0.8871 1826 2.3799 2058 42A5 6/9/2006 Psuedo SITP 192 0 2010 0.8797 2403 2.1551 2732 42 -05X 8/3/2006 SITP/ BHP PBU 15 0 1875 0.8801 2256 2.1976 2563 42 -05X 8/24/2006 _SITP /BHP PFO 12 0 2400 0.8851 2886 1.9949 3261 42 -05X 9/7/2006 SITP 24 0 2826 0.9004 3396 1.7610 3772 42 -05X 9/26/2006 SITP 24 0 3347 0.9290 4000 1.4678 4306 42 -05X 10/3/2006 SITP 53 0 3312 0.9267 3958 1.4422 4271 42 -05X 10/6/2006 SITP 11 0 3309 0.9265 3955 1.4390 4269 42 -05X 10/17/2006 SITP 107.5 0 3245 0.9234 3896 1.4127 4219 42 -05X 10/20/2006 BHP PFO 8 7794 3241 0.9216 3862 1.4015 4191 42 -05X 11/8/2006 SITP 31.5 0 3445 0.9358 4118 1.2840 4401 42 -05X 11/16/2006 SITP 44.5 0 3403 0.9328 4067 1.2497 4360 42 -05X 1/7/2007 SITP 89 0 3469 0.9374 4146 1.1109 4423 42 -05X 4/20/2007 SITP 20 0 3794 0.9626 4534 0.8318 4710 42 -05X 5/22/2007 SITP 8 0 3755 0.9583 4473 0.7523 4668 42 -05X 8/28/2007 SITP 12 0 3715 0.9561 4440 0.5834 4644 42 -05X 11/26/2007 SITP 840 0 3815 0.9644 4560 0.4622 4728 2/23/2009 0:1NAU\MCBU\ Alaska1Depts1AssetDev \CIGas1USERSIPMWIGas StoragelSwanson River\SCU 42 -05 77 -3 Sd POZ 2- 17- 09.xls 42ABXY -5 POZ data • • ATTACHMENT #2 SRGSF #3 - P/Z VS. CUM PRODUCTION DATA (Tyonek 77 -3 Sand) Parameter Value Units Gas Gravity 0.563 Bench Datum 7811 ft (tvd) Datum Temp. 141 ° F Datum Temp. 601 ° R Initial Z Guess 0.88 iauge - Test Measured Datum Duration Test Depth Pressure at Pressure, Wellname Date Test Type (hrs) (MTD), ft MTD, psia Z Factor Psia Cum Gas, bcf P /Z, Psia 2008 Production Cycle 42 -05X 12/14/2007 SITP 89.5 0 3647 0.9507 4359 0.5166 4585 42 -05X 1/4/2008 SITP 31 0 3258 0.9231 3890 0.6896 4214 42 -05X 1/23/2008 SITP 7 0 2676 0.8934 3199 0.9690 3581 _ 42 -05X 2/8/2008 SITP 10 0 1990 0.8797 2379 1.2923 2704 42 -05Y 2/13/2008 SITP 27.3 0 1909 0.8800 2282 1.3859 2593 2008 Injection Cycle 42 -05Y 5/16/2008 SITP 24 0 3668 0.9476 4311 0.783 4549 42 -05Y 6/6/2008 SITP _216 0 3771 0.9552 4427 0.686 4635 42 -05Y 7/6/2008 SITP 96 0 3915 0.9663 4587 0.567 4747 42 -05Y 9/22/2008 SITP 96 0 3796 0.9571 4455 0.431 4655 42 -05Y 10/7/2008 SITP 96 0 3857 0.9618 4523 0.427 4703 2008 / 2009 Production Cycle 42 -05X & Y 11/13/2008 SITP 72 0 3214 0.9182 3796 0.660 4134 42 -05X & Y 11/30/2008 SITP 24 0 2847 0.8995 3372 0.853 3749 42 -05Y 12/8/2008 SITP 96 0 2719 0.8942 3222 0.941 3603 42 -05Y 1/14/2009 SITP 24 0 1518 0.8880 1792 1.654 2018 42 -05X & Y 2/21/2009 SITP 48 0 1777 0.8816 2104 1.748 2386 2/23/2009 0:\ NAU\ MCBU1AIaska1DeptslAssetDev \CIGas1USERS\PMW\Gas StoragelSwanson River \SCU 42 -05 77 -3 Sd POZ 2- 17- 09.xls 42ABXY -5 POZ data ATTACHMENT #3 SRGSF #3 - POZ vs Cum Gas Production Plot (Tyonek 77 - 3 Sand) 6000 A Primary 1'05 -'06 Inj Cycle 5000 - A'06 Prod Cycle A 0'06 -'07 lnj Cycle 0 4. A'07-'08 Prod Cycle 4000 E. . _ 0'08 Inj Cycle ' • 08 - -'09 Prod Cycle • a 3000 - a ' • . • 2000 - ) 1000 • 0 0 1 2 3 4 Cum Gas Produced, bcf 2 / 23 / 20090 \NAU \MCBU \Alaska \Depts\AssetDev \CIGas \USERS \PM\MGas Storage \Swanson River \SCU 42 -05 77 -3 Sd POZ 2- 17- 09.xls AOGCC (090223) • ~~~. _, ~ ~. ~~ _ ~ ,. ~~ ~~ ~~ ~. ~~ ~ ~ ~ Y '~. :~~~~ ,~ «'' MICROFILMED 6/30/2410 DO NOT PLACE ANY NEW MATERIAL UNDER THIS RAGE C:\temp\Temporary Internet Files\OLK9\Microfil'm_Marker.doc ~~ ~ DATA SUBMITTAL COMPLIANCE REPORT 7/20/2009 Permit to Drill 2070820 Well Name/No. SOLDOTNA CK UNIT 42-05Y Operator UNION OIL CO OF CALIFORNIA API No. 50-133-20570-00-00 MD 8110 ND 8041 Completion Date 8/28/2007 Completion Status GSTOR Current Status GSTOR IC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATAINFORMATpN Types Electric or Other Logs Run: USIT, LWD - GR-RES - NEUTRON DENSITY (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ly IYIeO/rfllll 19YIIIYCI Na(Tje J4P~6 InGU~a ryV JLCIfL JIV~ Vf7 RCl.C1VCU VVIIIIIICIIW og Induction/Resistivity 5 Blu 297 8110 Open 10/15/2007 MD MPR, Nuetron Porosity, Bulk Density, GR mem Log, 11-Aug-2007 og Induction/Resistivity 5 Blu 297 8110 Open 10/15/2007 TVD MPR, Nuetron Porosity, Bulk Density, GR mem log, 11-Aug-2007 og Induction/Resistivity 2 Blu 297 8110 Open 10/15/2007 MD MPR, Nuetron Porosity, Bulk Density, GR mem Log, 11-Aug-2007 Log Induction/Resistivity 2 Blu 297 8110 Open 10/15/2007 TVD MPR, Nuetron Porosity, Bulk Density, GR mem Log, 11-Aug-2007 ED C 15537 Report: Final Well R 0 0 Open 10/15/2007 Final well Report, LAS, PDF Logs, Morning Reports, LAS report, Samples all in PDF or Word Log Cement Evaluation 5 Col 1 2400 7995 Case USCE, USIT, GR, CCL 14- Aug-2007 og 15824 Completion 5 Col 7450 7720 Case 1/7/2008 Competion Correlation log, CR, CCL 16-Aug-2007 w/PDS graphics ', ~g 15824 Sonic 5 Col 2400 7995 Case 1/7/2008 USIT, UCE, GR, CCL 14- I Aug-2007 w/PDS Graphics ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 7/2012009 Permit to Drill 2070820 Well Name/No. SOLDOTNA CK UNIT 42-05Y Operator UNION OIL CO OF CALIFORNIA API No. 50-133-20570-00-00 MD 8110 ND 8041 Completion Date 8l28/2007 Completion Status GSTOR Current Status GSTOR UIC Y Well Cores/Samples Information: Sample Interval Set ` Name Start Stop Sent Received Number Comments ~ Cuttings 1000 8110 8/13/2007 1181 ADDITIONAL IPFORM ION ~ Well Cored? / Daily History Received? ~~ N ~ ~/ Chips Received? l'fTFT1 Formation Tops l~Y~' N Analysis ,~(~ Received? Comments: ~its~~-n,e~ :l~ ~. t~-. +~We}4lM, V~ y i~'S ~ 3, Q~~i ~~ ~ ir~v1 i~.~+l S cl V`~ ~' ~. f~ ~ °• ~ • ~~-~ ~, ~.,~,,rc,.~~~ r-, c~~ Lr.~ ro ~..,,~,~ ~-~G~~~ ~~ ~« ~ V ~, ~. ~ ~,~ ~ `~ ~~~-~~q Compliance Reviewed By: __ Date: r~ ~ ~ ~ \J September 24, 2009 To: AOGCC Howard Okland 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Rec ' d By: ~~ Date: ~ ~ ~~~ r ~L7- G~'a ~ . . • . . ~ ~ Page 1 of 1 Okland, Howard D (DOA) From: Okland, Howard D (DOA) Sent: Tuesday, September 22, 2009 1:06 PM To: 'Oudean, Debra' Cc: 'fcbn@chevron.com'; Mahnken, Christine R(DOA); Davies, Stephen F(DOA); Saitmarsh, Arthur C (DOA) Subject: SCU 42-05Y Debra, We are missing open hole logging digits for the SCU 42-05Y ( API 50 133 20570 00 ) We also are missing any graphics files of the open hole logs. Paper copies of the logs were sent to us in October of 2007. Additionally, we need a digital copy of the directional survey. Please send the missing data to us, to my attention. TNX, Howard 9/22/2009 ~ ~ Chevron FranCisco Castro Chevron North America Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 ~ Fax: 907 263 7828 E-mail: fcbn@chevron.com 7anuary 3, 2008 To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 ~ ~ ~ ' ' ' II i*"*k ~ Y$.f.~~~ '~ ` `~" ~- ~ " ~ ~ ~ g/-~ X3yi, 5Ai'i~S ~ ,~' ~ &~ .~ ~~'~5~ ~"~ ~ f ~ ~ `~ .. ~ ~-£ ~ i .-3.k '~} ~e a . ~4 .:~-~ ` P ,~~~s ~ ~t'r~'~R ,'F'E~ ~ ~ ~ ~, t ~+Js ~` ~as~~,~ ' ~~'4' ~ c ~, ~ ^~[.~ ~ ~~ ~.. ~a ~ ~TES"~ i ~ - ~. ~ m< "~ ~ ~~ ~~~~ ~ ~~ z ~~t~~~ ~ ~" ~: ~~~~ ~ ~ , ~ '~~~°~~~ ~~ ~~~. ~ ~ G~~~ ~~ ~ ~~ ~`~ ~ ~~§ A~ IN~,~ ~ ~ ~~ ~ ~ G ~E~ ~~~ ~ ~ ~RUNS ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ` ~ ~` ~~`~ ~~~~~~~~ t " ~ ,~, °~~~~ ~ ~ ~ ~,~~ ~ ~~'`~~ ~ ~~. ~ ~~~~~ ~... ,~ ~~ = ~ ~; ~ ~ ~ r . . COMPLETION CORRELATION 7450 - SCU 42-05Y LOG GR/CCL 5" 16-Au -07 7720 1 1 PDS ULTRASONIC CEMENT EVALUATION 2400 - SCU 42-05Y USIT/GR/CCL 5" 14-Au -07 7995 1 1 1 PDS u-~ c2~~""°~ a ~ ~ 5~~ ( , ; ~ ~ w_ ~ ~: , ,. 3' } ~ # y .~ 5i Please acknowledge receipt by signing and returning one eopy of this tra sr~i'~ta''~ or ~AX to 907 263 7828. Received By: Date: ar'~ ~' '~`';~ ~/ _ , . ~ , _ ~ .. , .. ~~ . .. ~ ~ Maunder, Thomas E (DOA) From: Walsh, Chantal [Petrotechnical] [WalshC@chevran.comj Sent: Tuesday, Octaber 30, 2ft~7 4:06 PM Ta: Maunder, Thomas E (DOA) Subject: RE: SCU 42-05Y (2Q7-082) Attachments: Productian casing moming reports.pdf; Surface casing moming repartsl.pdf Tom, Page 1 of 2 I have attached the morning reports, from the point of tripping out of the hole with drill pipe to rigging down the cement equipment, for the cementing of the surface and production casing. Please contact me if you have further questions or requests. Chantal From: Maunder, Thomas E (DOA) [mailta:tom.maunder@-alaska.gov] Sent: Tuesday, Uctober 30, 2007 9:4Q AM To: Waish, Chantal [Petrotechnical) Subject: RE: SCU 42-~5Y (207-U82) Chantal, Thanks for the information. This is informative, however what I really need is the report/summary prepared by the Chevron supervisor fior both jobs. I also request the operations details beginning with the trips out of hofe to run casing through rigging down after the jobs completions. Call or message with any questions. Tom Maunder, PE ROGCC From: Watsh, Chantaf [Petratechnica[] [mai{to: WalshC@che~ran.eom] Sent: Tuesday, October 30, 2U07 8:37 AM To: Maunder, Thomas E (DOA} Stibject: RE: SCU 42-05Y (207-082) Tom, I have attached the cement reports for the surface and production casings on the SCU 42-05Y well. During the cementing of the surface casing, +/- 100 bbls of G neat cement sturry was circulated to surface. In response to Chevron increasing the volume of cement pumped over the volume presented in the drilling application, it was our intent to pump the volume necessary to establish cement to surface on the surface casing and cement ta the height of +/- 4000' TVD in the production casing. With both the surface string and the production string, a marker was pumped ahead of the cement operation to give an indication of hole size. Based on the results, the final volumes of cement were established. Do not hesitate to contact me if you have further questions. Chantal From: Maunder, Thomas E (DOA) [mailto:tarn.maunder@alaska.gov] Sent: Monday, October 15, 2(3Q7 2:43 PM To: Walsh, Chantal [Petrotechnical} Cc. Buster, Larry W Subject: RE: SCU 42-f)5Y (2a7-082} 12/17/2047 ~ ~ Page 2 of 2 Thanks Chantal. I will look for the transmittal. Interesting on the new drill pipe. That is a prudent practice, I'd not seen the practice "required" before. Call or message with any questions. Tom Maunder, PE AOGCC From: Walsh, Chantal [Petratechnical] [mailto:WalshC@chevran.c~rt] Sent: Monday, Octaber 15, 2007 11:36 AM To: Maunder, Thomas E (DOA) Cc. Buster, Larry W Subject: RE. SCU 42-05Y (207-082) Tom, I will submit the cement report and the amount of cement that was circulated for surface and production casing. Also a comment of the volume increase over what was stated in the permit application. I will do this under a letter with the attachments. The metal shavings were reported for the BLM. We had new hardbanded drill pipe on location and had to apply for a variance from the BLM. The condition of the variance was: + report the amount of inetal retrieved from ditch magnets installed in the shaker on a daily basis, . after drilling out of the 9-5/8" surface casing for approximately 2500 fee# trip out of the hole and run back in with the "just run" pipe swapped on top of 250p' of new pipe to minimize the circulating time of new pipe in the 9-5/8" casing, • perform a 1500 psi pressure test of the 9-5/8" casing . establish a contingency plan to cement the annular volume between the 9-5/8" surface casing and the 7" should the integrity test show integrity for the 9-5/8" casing could not be achieved. We had very few metal shavings which we weighed every tour and reported to the BLM. They did not have their inspector come out to observe the shavings. The hard banded pipe we ran is the new kinder, gentler hardband pipe specifically designed to minimize abrasiveness to casing. The pressure test for the 9-5/8" casing was fine. Please let me know if you need additional information on the BLM variance. Chantal From: Maunder, Thamas E (DOA} [mailta:tom.maunder@alaska.gov] Sent: Friday, Cktober 12, 2007 1:05 PM To: Walsh, Chanta! [Petrotechnicat] Cc: Suster, Larry W Subject: SCU 42-05Y (2d7-082) Chantal and Larry, I am reviewing the compfetion repart (10-407} for this wefl. 1 am requesting same addi6onal information. 1. Please provide the eementing reports for the surEace and production casings. 2. On the surFace casing, please indicate how much cement was circulated. 3. Based on the in#omration submitted, it appears that the cement vaiumes on k~th strings were increased over what was stated in the permit application. I'd appreciafe a comment regarfding the votume increase. 4. Metal shavings are reported while drilling in tlie 9-5/8° casing and it wauid appear that was due tt~ emplaying new dritl pipe. tt appears that BLM requir~ci the pipe to be shifted into the open ho~ artd that a casing pressure tes# be performed. Was the appearance af inetal shavings reported to B!M or were the shavings obsenred by their inspectot'? Thanks in advance. Cali vr message with any questions. Tam Maunder, PE AOGCC ~2i1~i2ao~ ~ ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, October 12, 2007 12:33 PM To: 'Oudean, Debra ; Ayer, Phil M Cc: Watsh, Chantal (Petrotechnica{]; Greenstein, Larry P; Kirschner, Khristina Subject: RE: SCU 42-05Y (207-082) Thanks much. I know there were lately some amendments of the Oil and Gas statutes regarding submitting reports and logs. I am not sure of the time requirements; however it does make reviewing completion reports easier if the logs are handy as well. Call or message with any questions. Tom Maunder, PE AOGCC From: Oudean, Debra [mailto:oudeand@chevron.com] Sent: Friday, ~ctober 12, 2007 11:13 AM To: Ayer, Phil M; Maunder, Thomas E(DOA) Cc: Walsh, Chanta{ [Retrotechnical]; Greenstein, Larry P; Kirschner, Khristina Subject: RE: SCU 42-05Y (207-082~ I will submit the logs for SCU 42-05Y today. I had to send out to get extra copies. Debra Froms Ayer, Phil M Sent: Friday, October 12, 2007 11:10 AM To: 'Maunder, Thomas E (DOA)' Cc: Walsh, Chantal [Petrotechnical]; Greenstein, Larry P; Kirschner, Khrist'rna; Oudean, Debra Subject: RE: SCU 42-05Y (207-0$2) Tom. We will reply to you early next week as to when you will receive the logs as the responsible party is out of the office today. If this is not acceptable please advise. We will also plan to get the logs to the AOGCC in a more timely manner in the future. Phil Phil Ayer MidContinent/Alaska Business Unit Chevron North American Exploration and Production Company 909 West 9th Avenue, Anchorage, AK 99501 907-263-7620 (work) 907-250-2711 (cell) 907-263-7847 (fax) 10/12/2007 ~ ~ Page 1 of 1 Maunder, Thomas E (DQA) From: Maunder, Thomas E (DOA) Sent: Friday, October 12, 20d7 '[0:35 AM To: Walsh, Chanta{ [PetrotechnicalJ; 'Larry Greenstein'; 'Ayer, Phil M' Subject: SCU 42-05Y (207-Q82) Alt, Not sure who shouid get this message. I am reviewinq the completion report (10-407} submitted at the end of September. In tate August t rnet with Chantat and a Schtumberger rep and examined the UStT fog. In ehecking the ft(es, t da not find that any logs have been submitted for our fites. When might we expeet to receive the Ic~gs? Thanks in advance. Call or message with any questions. Tom Maunder, PE A~GCC 10/12/2007 ~ ~ Chevron - Alaska Report Date: 7/20/2007 ,; Joint Venture Morning Report Report No.: 22.0 ~"" Days from Start: 17.44 Well Name Field Name API/UNA Lease/Senal Ong KB Elev (ftKB) Water Depth (ft) SCU 42-05Y Soldotna Creek 50-133-20570-00 1A020896 20.5 -- Pnmary Job Type ~~~- pnmary Wellbore Affected Drilling - Original Original Hole Cook Inlet Basin • Soldotna Creek Gas Storage I. AFE Number . Total AFE Amount Working Interest (%) Target Depth (ftK6) Target ND (ftKB) , Supp AFE No. Total AFE Sup Total AFE+Sup S7000 I 4,938,067.00 100.00 8,130.0 8,050.00 ' 4,938,067.00 Daily Cost Total Cum Cost To Date Drilling Hours (hrs) Average ROP (fUhr) ~ Depth Start (ftK8) Depth End (ftK8) 92,546.49 735,988.11 2.00 37.5 2,985.0 3,060.0 Weather ~ Temperature (F/C ) Wave Conditions W ind Head Count ; 59.0 00:00 - 5:00 Summary Rig up to run 9 5/8 csg. Dummy run fluted hanger to welhead/run 9 5/8 csg. Operations Summary Drill from 2985' - 3000'. Circulate and condition hole. Rotate/reciprocate pipe. TOOH. Circulate and condition hole, TIH. Drill 3000' - 3060'. Condition mud. Pump nutplug marker. TOOH. LD BHA. PTSM on PU casing tools, laying out BHA, tripping, wellcontrol and LD BHA. SIMOPS. Mud Wgt = 9.9Pp9 ~ 00:00 ~ 1.OOI01:00 ~ Drill 2985'-3000' - 80 RPM, TRQ 3-6, WOB 10, ROP 150, ROT WT 81, PU 81, SO 81, 13.5 BPM @ 1200 PSI ;01:00 1.50~02:30 Circulate and condition hole, rotate/reciprocate pipe, 13.5 BPM @ 1200 PSI ' - __.._--- -. 02:30 4.OO106:30 TOOH 3000'-300' - PU 82, SO 81. Slight drag at 2450', 1630', 1119-675'. 06:30 1.00107:30 Circulate and condition hole, prep to TIH 07:30 ---'- 3.00~ 10:30 -- -__---- ---- ------ TIH 300'3000', PU 81, SO 81, wash through spot at 2940. 10:30 1.00;11:30 ' Drill 3000' - 3060' to fit casing talley with 8' of rat hole below shoe. 80 RPM, TRQ 3-6, WOB 7-10, ROP 100, 13.5 BPM at 1400 PSI. --- - 1130 1230 ~ ---- 1_00`12 30 2.00!~14:30 --- --- -- - Circulate and condition hole for casing with 13.5 BPM at 1400 PSI. Finish cond. mud. and pump nutplug marker around _ ~ 14:30 2.50i17:00 TOH 17:00 4.50! 21:30 ---------- -- - Download LWD and lav down BHA i 21:30 ~ 2.50i00:00 Finsih w/BHA. Get 12 1/4 BHA ready to ship to Anchorage, clear rig floor, wash same, wash stack and pump out cellar and get I j Weatherford casing equip staged for picking up. , ~ ~~",•~~ ~/ ~i ~~„/i/ ~~ , ~~~ ~ ~%: ~ ~ ~ji/la. ?i ~ ~ "~ . :; „. ,i, . ~ ~ //y/ aR. ~./.i..,/,. .~,..~i.. .',., /'~ /.: . . ..,. ; , .. '; < .. .....~~~ ..~ . . ~.:"'y~ SIII"~'.C19SGriPtICM~:, ~ : ~~~~. ;...,': ; C3Q(iFt}'.:, .", ICt~~R} ~ ~Yl?t(IbS#ft}.. _:.: Gr2d0 , ~°. (ftKE~): `% - ,.. ~. ~ ~' . . . . .:.:. ~ ....i v , . ..... . . .; ....., i „-, ~ ~~:~. Surface 9 5/8 ~ 8.681 47.00 L-80 j 3,054.3 Surface Casing, Hole TD 3060' MD ~ ~ Chevron - Alaska Report Date: 7/21/2007 Joint Venture Morning Report Report No.: 23.0 Days from Start: 18.40 Well Name SCU 42-05Y Field Name API/UWl ~Soldotna Creek 50-133-20570-00 ~ ~~ ~ --~ ~ease~senal ~ A020896 Ong KB Elev (ftK6) - 20.5 __ ____,--- Water Depth (ft) Pnmary Job Type Pnmary Wellbore Affected Drilling - Original Original Hole ~ ~~ _ _ _ _ _ Area Field Name Well Class I Water Depth (ft) Cook Inlet Basin Soldotna Creek Gas Storage ~ AFE Number ; Total AFE Amount -~Working Interest (%) Target Depth (ftK6) ~ rTarget TVD (ftKB) Supp AFE No. ~Total AFE Sup ~Total AFE+Sup S7000 ~ ~ 4,938,067.00 100.00 8,130.0 8,050.00 I 4,938,067.00 Daily Cost Total ! Gum Cost To Date Dnlling Hours (hrs) Average ROP (fUhr) Depth Start (ftK6) Depth End (ftKB) 163,661.23 ~ 899,649 34 r __ --- -- ~ ----- ~ 3,060 0 3,060.0 ~ Weather ~ Temperature (F/C) Wave Conditions --- -------- Wind - - - . _ _.. - ~~~~ ~~~~ Head Count ~ ~ 62.0 00:00 - 5:00 Summary ~ ND Diverter System OperationsSummary - ---- -"-- Finish LD BHA. MU hanger and landing joint. PU 75 jts of 9-5/8", 47#, L80, Mod Buttress Csg. Shoe set at 3054, float collar at 2971. 21 Centralizers placed. 1 each on the bottom 3 JTS and 1 every 4th to 100'. Circulate, PU cement equipment. PJSM. RU cement lines, drop bottom plug, pump 279.7 bbls lead slurry, 61.6 bbls tail, drop top plug, bump plug, hold pressure at 3000 psi for 30 mins. PTSM on running casing, casing handling hazards, cementing hazards and nipple down operations. SIMOPS with production. Mud Wgt = 9.8ppg 00:00 I 1.50j 01:30 i, Finish laying down directional BHA and handling tools. Clean rig floor 01:30 0.50102:00 i Make up hanger and landing joint. Dummy run with hanger and verify space out. --- -- --------- _..__ _-- - 02:00 3.00 ~ 05:00 ~i RU to run 9 5/8" casing. Change bales, RU tongs. 05:00 7.00112:00 PU and run 75 JTS of 9 5/8", 47", L-80, Modified Buttress casing. Shoe set at 3054.29', float collar at 2970.63'. Float operation I. verified. Thread lock bottom 5 JTS. 21 centralizers placed 1 each on bottom 3 JTS, and 1 every 4th to 100'. Circulate and wash I last 6' to landing depth. PU 124, SO 115. -~ _ __ _---- - - - ------~ ~ 12:00 1.00 13:00 i P/U and M/U Circ. head and plumb same to schlbgr. 13:00 3.50 16:30 Circulate @ 80 SPM ( 5 Bbl/min.) Lay down casing tongs and hand tools, running equip. P/U cementing equip. - -. --_ __ _ _- --------- 16:30 2.50 19:00 I Circulate, load plugs in cement head, M/U head and hoses and cirulate ... Up wt= 124K, Dn wt.=118K, -- - - ---- - - - - ------ -- ----------- - 19:00 4.00 23:00 PJSM , Rig up and test cement lines to 3000 psi. pump, pump 5 bbl water, pump 40 bbl mud push, Drop bottom plug, pump lead slurry (279.7 bbts Class G Extended @ 12.8), (verified plug launched) switch over to tail (61.6 bbis Ciass G@ 15.8), line up for displacement, drop top plug and verify launch, displace w! cement pump @ 7 bbl/min. slow to 2.5 bbl/min and bump plug and hold press at 3000 for 30 min. Cement to surface 127 bbl into displacement (93 bbl cmt circ to surface). Press. test good. End cement job on 47# 9 5/8" casing. I Surface ~ 9 5/8 ~ 8.681 I 47.00 I L-80 I 3,054.3I Surface Casing, Hole TD 3060' i ~ Cook Inlet Basin ~ Soldotna Creek I Gas Storage AFE Number ~ Total AFE AmouM ~ ~ Nlorking Interest (%) ~Target Depth (ftKB) Target ND (ftKB) Supp AFE No. Total AFE Sup Tota~ AFE+Sup - ~ S7000 4,938,067.00 ~ 100.00 8,130.0 ~ ~~ 8,050.00 i 4,938,067.00 Daily Cost Totai ~ Cum Cost To Date Drilling Hours (hrs) ~Average ROP (fUhr) Depth Start (ftKB) , Depth End (ftKB) ~ 90,162.16 -- --- 989,811.50 i 3,060.0 3,060.0 ' Weather Temperature (F/C) Wave Conditions VNnd ~- ~ Head Count - _-- 1 ~ ~ 53.0 : 00:00 - 5:00 Summary ---- --- - - -------------- ._--- --..._-- - Nipple up BOPE Operations Summary RD cementers. Nipple down diverter system. Nipple up BOPE. Held Safety stand down. PTSM on driving safety, nipple up operations. SIMOPS with production. 00:00 2.00 02:00 Rig down Schlumberger cementing equip and landing jt. and flush cem fdrom stack. Clean out underneath shakers and clear and clean rig floor. --------- _-- ----- ___ -- _ __ _- - - ------ 02:00 6.50 0830 i Nipple down diverter system and knife valve. , rig down and move catwalk and beaver slide. Breaking hard cement out of slop I tanks ____ -- --------- -- _ 08:30 1.00 0930 ~ Prep wellhead , prep to nipple up BOPE 09:30 ~ 14.50 00:00 ', Nippie up BOPE, cleaning hard cem from slop tanks. Had 30 to 40 minute rig " Safety Stand down" with all NAD handdsand all on i , location and Chevron reps from G8~1 and discuss Chevron commitment to safety and the several minor incidents of the last few i j days and how to stay focused and avoid incidents of all kinds. Each DSM gave input and several hands spoke out on safety and I ! Chevron policies as well. Good meeting. 9 5/SI 8.6811 47.OOIL-80 Chevron - Alaska Report Date: ~iz~r2oo~ Joint Venture Morning Report Report No.: 24.0 Days from Start: 19.40 ~ ~ -------- ~~"'~'~ ------------ Chevron - Alaska Report Date: 8/11/2007 , Joint Venture Morning Report Report No.: 44.0 Days from Start: 39.42 Well Name Field Name API/UWl ; Lease/Serial Orig KB Elev (ftKB) Water Depth (ft) SCU 42-05Y Soldotna Creek ~50-133_20570-00 IA020896 20.5 Pnmary Job Type Pnmary Welibore Affected ~~ ~ Drilling - Original Original Hole Cook Inlet Basin Soldotna Creek ~Gas Storage AFE Number Total AFE Amount Working Interest (%) I Target Depth (ftK6) Target ND (ftKB) Supp AFE No. Total AFE Sup Total AFE+Sup ~ S7000 4,938,067.00~_ 100.00_~ 8,130.0 8,050.00 4,938,067.00 Daily Cost Total Cum Cost To Date Drilling Hours (hrs) Average ROP (fUhr) ~ Depth Start (ftKB) Depth End (ftK8) 115,839.76 3,549,551.65 1.50 16.7 ~ 8,085.0 8,110.0 Weather Temperature (F/C ) Wave Conditions Wind Head CouM Fog/Clear ( 65 n/a ----... -- 15-10 --------- - 55.0 ~ -- - -- -- . - 5:00 Summary i Run 7", 26#, TC II Production Casing , j Operatfons Summary ; Finish Drilling to FINAL TD of 8110', TOOH, LD BHA, C/O Rams to 7" CSG Rams and Test, Test run Hanger, RU CSG Tools, Start Running 7" CSG. Mud ' Wgt = 12.4Pp9 ~ 100:00 ~ 0.50 ~ 0030 I Finish installing new stud bolts on #1 mud pump thread ring flange 100:30 1.50 02:00 Drill 8085'-8110', 65 RPM, 4-5 TRQ, 440 GPM @ 3100 PSI, 15 WOB, PU 130, SO 120, ROT 120 102:00 3.00 05:00 Circulate up mud loggers samples, Pump 26 bbl 200 vis sweep, pump carbide flag. Carbide flag indicates 23% washout. 05:00 6.00 11:00 Flow check, TOOH into casing shoe at 2995'. Flow check at shoe. Finish TOOH to BHA at 975'. ~ ------ ---- -- ' 19:00 6.00 17:00 LD MWD/LWD BHA, motor and bit. 17:00 2.00' 19:00 Change out bottom pipe rams to 7" casing rams. Test rams to 250 low and 5000 high for 30 minutes and chart. ' -- -------- _ _ ~ 19:00 3.50~22:30 RU casing tools and prepare to run 7" 26# TC II Production Casing. PU and test run hanger and landing assembly. 22:30 I 1.50~00:00 I Make up shoe track, check floats, and start running casing. 11 JTS run by 24:00 to 467' 9 5/8 ~ 8.681 i 47.00~ L-80 ~ 3,054.3I Surface Casing, Hole TD 3060' MD I ~ ~ Chevron - Alaska Report Date: 8/12/2007 Joint Venture Morning Report Report No.: 45.0 Days from Start: 40.42 Well Name ~- Field Name API/UVN Lease/Senai Ong KB Elev (ftKB) Water Depth (ft) SCU 42-05Y Soldotna Creek ~50-133-20570-00 !,A020896 26.5 ~ --- -- -~--------- Primary Job Type Primary Welibore Affected Drilling - Original Original Hole Cook Inlet Basin Soldotna Creek ~ Gas Storage AFE Number Total AFE Amount Working Interest (%) ~ Target Depth (ftK8) Target TVD (ftK8) Supp AFE No. Total AFE Sup Total AFE+Sup S7000 4,938,067.00 100.00 8,130.0 8,050.00 4,938,067.00 Daily Cost Total ~~ ~~~~ Cum Cost To Date Dnl~ing Hours (hrs) Average ROP (fUhr) Depth Start (ftKB) Depth End (ftKB) 147,189.55 3,696,741.20 8,110.0 8,110.0 Weather Temperature (F/C) ~ Wave Conditions Wfnd Head Count Ciear 65 n/a 5 57.0 --- -- 00.00 - 5:00 Summary ------.__----- -- Cement 7" CCG, RD CMT equipment, pull landing JT, Run Pack-off and test. Operations Summary . - - Finish Running 7" CSG, land, Break Circ w/ No Returns, RU CMT head, RU cement equipment, Mix mud push, Batch mix cement, Press Test CMT lines, start cementing operations 00'00 I 5.00 I05:00 ~ Run 7", 26#, L-80, TC II production casing 467'-3029'. PU 78, SO 62 05:00 I 1.OOI06:00 ~Circulate 1/2 casing volume 75 SPM @ 135 PSL 06:00 i, 9.OOi 15:00 I Finish Runing 7", 26#, L-80, TC II production casing. TD at 8110', Bottom of Float shoe at 8099.09', Top of Float Collar at 8013.97', 14.79' Marker JT at 7796'-7811'. Run 1 centralizer each JT up to 4582', 1 at 4010', 2953', and 119'. Total of 90 i centralizers run as per program. Pipe run right to bottom w/ no troubles. At TD PU 144, SO 127. 15~00 1.OOi 16:00 Break Circulation with 25% retums. Circulate with varying returns between 10 and 25%. Pipe free while pumping, PU 127, SO ~I ~ 120.Shut down pumps with 150 bbis left in surface mud pits. 16:00 I 7.00~23:00 RU cementing equip, Batch mixers, cement bulk tanks, lines to KCL displacement tank. Mix 40 BBL mud push spacer at 12J ppg ~ in pill tank and transfer to vac truck. Batch mix cement in batch units. Pump 10 bbl on hole with mud pump #2 at 30 min intervals ', with very little retums. 23:00 ; 1.00100:00 Test CMT lines to 5000 psi. Pump 40 bbl mud push spacer at 12.7 ppg. Drop btm plug. Start pumping cement from batch mixers ~ i 193 total bbl of 13.2 ppg FIexSTONE - flex13.23+.7gpsD500+.030gpsM045+.4%D065+.1gpsD177+1%D174+.02gpsD135, yield j ; 1.43 ft3/sk, 4789 gal/sk mix water 47 ~ ~ ~~ , t~ Chevron - Alaska Report Date: 8/13/2007 ,. ,,_, : Joint Venture Morning Report Report No.: as.o " Days from Start: 41.42 Well Name ~ ~ ~- ~~~- ~ Feld Name ~ ~~ ~ APUUWI ~ i Lease%Senal ~ - ~ ~ -~ - Ong KB Elev (ftK6) Water Depth (ft) SCU 42-05Y lSoldotna Creek _~50-133-20570-00 ' A020896 ___ ~__ 20.5 ~__ Pnmsry Job Type ~~ ~ Pnmary Wellbore Affected Drilling - Original Original Hole Area j Field Name Well Class ~~~ ~ ~~ Water Depth (ft) i Cook Inlet Basin ~ Soldotna Creek Gas Storage AFE Number ~ Total AFE Amount Working Interest (%) Target Depth (ftK8) Target ND (kK6) Supp AFE No. Total AFE Sup Total AFE+Sup S7000 ~ 4,938,067.00 100.00 8,130.0 8,050.00 , 4,938,067.00 Daily Cost Totaf ~ ~ Cum Cost To Date Dnlling Hours (hrs) ~Average ROP (fVhr) Depth Start (ftK6) Depth End (ftK8) 264,292.03 3,961,033.23 ! 8,110.0 8,110.0 ~Neather Temperature (F/C) Wave Conditions j W ind Head Count Clear I 65 n/a 'Calm 52.0 J0:00 - 5:00 Summary Cleaning mud pits, prepare to displace w/ clean KCL ~perations Summary - Finish CMT 7" CSG. Pumped 192 bbls of Flexstone Cmt, install P/O and test, C/O Rams and Test, install W/B, TIH w/ 6" bit, Drill CMT, Clean Pits, WOC 00:00 4.oU;04:o0 F)nlsh cementfng 7", 26#, TC II production casing. Cement detaiis on 8/12 report. Pumped total of 193 bbl 13.2 ppg cement, displace w/ 308.25 bbl (total disp + 1/2 shoe track vol) 6% KCL, piug did not bump, FCP 1859 PSI, bleed off pressure and check -- - ' floats (good). RD cement head and equipment. 04:00 2.50I 06:30 ----- _--- - Back out and LD landing JT. Install Pack-off. Test pack-off to 5000 PSI for 30 min. Pack-off installed by Vetco Gray and Clint Chanley. 0630 T 3.501 10:00 PU test stand, install test plug and lock down. Change out bottom pipe rams from 7" CSG rams back to 4" pipe rams. Test 4" pipe I ~ rams to 250 psi low and 5000 high and chart. LD test stand and test plug. Install wear bushing. 10:00 3.501 133~ Clean mud pits to be able to displace and circulate 6% KCL completion fluid. ------- - 13:30 1.50 15:00 - - - -_ ._ PU 6" mill tooth bit, bit sub w/ float, and XO. TIH on 4" HWDP and DP to 4600' --- - 15:00 2.00 17:00 - ------------- Slip 120' of drill line, fill pipe, service top drive, transfer 60 bbl KCL to mud pits from frac tank. 17:00 2.50 ~ 19:30 Finish TIH 4600'-7885', tag cement at 7885' (129' above float collar at 8014', 5 bbl short on displacement). PU 130, SO 124, ROT ~ 126. 19:30 I 2.00 21:30 _..- _- Drill cement 7885'-float collar at 8014', 45 rpm, 4,9 bpm 21:30 1.00 - 2230 ---- -- --- - ---- _ Circulate hole clean. 22:30 1.50 00:00 -- - -- --- - -- - Cleaning mud pits to displace hole over to clean 2% KCL. Work pipe every 30 min to ensure free. When pits are clean and new I ~ I KCL mixed, will displace hole and TOOH for USIT bond log. WOC minimum 40 hrs (18:00 on 8/14). 'Surface ~~%~ L ~~~ ° oc~ <<S 50 ~~a-~ ~~ fl~ ~ I I '~ ~~ ~ ~ ~ ~ Well Field Service Date Soldotna Creek Unit #42-O5Y Swanson River I~ Ds'ti+~ T~~'18 ' TI'~d#9ng CMT itATE Dens3iy CM7 S'I`GitaL 6MT Up4,~ as ~~ Presst~[e •' c~~+ck psi dbNfinltl~~ lb~g`~a! ~~ brik ~~ l~bl' . ~~ A ~~~, ~~~. a .~ 2007-Aug-12 20:56 ~ 1552 L 0.0 8.31 0.0 2.9 Customer Jtfb~~uknbeY '~ CHEVRON CORPORATION ,':•22~09~t1307 ~~~ ~) ~ IVM€~~}~; ~ E 0~~ ~.. tt ~~° F~ ~. ~ r~- ~~~ .._ -_ . 0 ~ 0 2007-Aug-12 20:57 i 5122 ' 0.0 8.31 0.0 ~ 2.9 0 0 2007-Aug-12 20:58I 32 i 0.0 8.31 OA I 2.9 0 I 0 2007-Aug-12 20:59 ~ 87 0.0 8.31 0.0 I 2.9 0 0 2007-Aug-12 20:59 ~ batch up cement ~ 2007-Aug-12 20:59' 87 0.0 8.31 0.0 ~ 2.9 0 0 2007-Aug-12 2007-Aug-12 23:20, -- - --- - 23:20 27 ~ - -- ---- ~ 0.0 I----- 8.31 - 0.0 ' 2.9 ~ 0 0 Start Pumping Spacer 2007-Aug-12 23:21 252 1.8 8.31 0.2 0.2 0 0 2007-Aug-12 23:22 ; 595 2.8 8.31 2.4 2.4 0 0 2007-Aug-12 2323 581 2.8 i 8.31 4.8 4.8 ~ 0 0 2007-Aug-12 23:23 572 2.9 i 8.31 7.2 7.2 ~ 0 0 -- -- 2007-Aug-12 23:24 ~ density = 12.8 Mud Push 2007-Aug-12 23:24 f 586 ---t-------_ --- 2.9 ---- 8.31 -- 7.8 - - 7.8 ~ 0 - 0 -- 2007-Aug-12 23:24 ~ 600 2.9 8.31 - 8.6 8.6 0 0 ---- 2007-Aug-12 23:24 I___ ~ took weight before job in peak vac truck 2007-Aug-12 - - 23:24~ 572 ~ 2.9 ~-8.31 ----t--- --------- - 9.6 9.6 0 0 2007-Aug-12 --- - 23:24 i -- _ -'-------- ' ------•----- ------ - - - ---- cannot go through MM here so ----- --__.____._-- __._.--------- not getting density I 2007-Aug-12 - ----- -- 2007-Aug-12 23:24 --- 23:25 ----- __ I i 581 I 568 i -- ----i n 2.9 i 2.9 ~ 8.31 8.31 10.4 --- 12.0 10.4 ' 92.0 ~ 0 0 0 0 - --- ~ 2007-Aug-12 2326' 563 i _ _..---- 2.9 --- 8.31 ---- 14.4 14.4 - 0 0 - ..._ ~ 2007-Aug-12 23:27 595 ' 2.9 8.31 16.8 16.8 0 0 2007-Aug-12 2007-Aug-12 23:28 -- 23:25 600 ~ - -- -----~ 558 ~ + 2 9 ~ ------ 2.9 8.31 8.31 19.2 21.6 19.2 21.6 0 --- 0 --~ 0 0 - -- ----- - - -- 2007-Aug-12 23:29 563 ; -------- 2.9 -- 8.31 24.0 24.0 0 0 - ---- 2007-Aug-12 23:30 568 i 2.9 8.31 26.4 26.4 0 0 2007-Aug-12 2331 568 + 2.9 8.31 28.9 28.9 0 0 2007-Aug-12 , _ 23:32 __ _- 572 - ------------ 2.9 - 8.31 31.3 31.3 0 0 2007-Aug-12 ------- _ _ _ 2333 577 ------ 2.9 - 8.31 - 33.7 33.7 0 0 - ---_- 2007-Aug-12 -- _ 2333 ._..-- 563 ---- 2.9 --- - 8.31 ~ - - ----- 36.1 36.1 -- 0 0 ---- 2007-Aug-12 23:34 j --- ---- End Spacer 2007-Aug-12 23:341 243 0.0 8.31 ~ 36.3 36.3 - ~ ~ 0 0 2007-Aug-12 23:34 I - _.-' ----------- - ___... --- --- Reset Total, Vol = 36.30 bbl 2007-Aug-12 23:34 i 233 - --- 0.0 --. 8.31 i 36.3 ! 36.3 0 _ 0 .._._._- 2007-Aug-12 23:341 169 0.0 11.97 ; 0.0 36.3 0 0 2007-Aug-12 2334 ~ ~ - 169 0.0 11.93 ~ 0.0 36.3 _ ~ 0 0 _ 2007-Aug-12 _ 23:34; ____..__~ ........_ ------ ' Drop Bottom Plug 2007-Aug-12 23:34 ------ ---- - --. _ ____ Start Cement Slurry 2007-Aug-12 23:34 165 0.0 11.92 OA ~ 36.3 0 0 2007-Aug-12 ------_..__ _ 23:35 .-- 142 ~ 0.0 11.92 0.0 ! - --- 36.3 0 - - 0 -- - - - ----- - 2007-Aug-12 - 2336 133 ~ 0.0 j 11.81 0.0 ~ 36.3 0 0 2007-Aug-12 ----.. __ - 23:37 -- -- 188 ~ 0.2 9 -__------ ----- .25 ----- 0.0 ~ 36.3 0 __, 0 - -- 2007-Aug-12 23.38 ~ j ~ 609 3.1 I 13.01 2.2 38.5 --- 0 _ 0 _ _. -- 2007-Aug-12 23:38 623 3.1 13.24 4.8 41.1 0 0 2007-Aug-12 - 23:39 ~ --._ 627 3.1 ' -. --- 13.14 7.4 437 0 0 2007-Aug-12 ----- -. , 23:40', . 613 3.1 _ _. _ - 13.02 - 9.9 ---- 46.2 0 ~ ------ 0 -- 2007-Aug-12 - 23:41 -- - 613 3.1 --- 13.14 i 12.5 48.8 0 0 -_--------- 2007-Aug-12 --- 23:42 - 645 ~ 3.1 - __ j - 13.24 ! ~ 15.1 - 51.4 --- --- 0 ; - 0 ~-- --. _ _ - - _... __-- 2007-Aug-12 2007-Aug-12 23 43 - 23 43 - 618 i 3.1 --- 659 , 3.3 13.25 i 13.25 ; 17 7 - 20 5 54.0 56.8 0 i 0 ~ 0 _ 0 ~ _ _ 2007-Aug-12 -- 23:44 - 682 I 3.3 13.27 i _ 23.3 ~ 59.6 0 i __ 0 _ - -- . _ _ - 2007-Aug-12 23:45 687 ~ 3.4 13.27 , 26.1 L 62.4 ~ 0 i 0 Aug 13,2007 WRS3 v3.414-SR Page 2 of 7 ~ ~ ~ ~ ~ ~ ~ ~ ---- -- ---- - - --------- ---- Welt Field Service Date Customer ~o&,~1Yf11peN _ Soldotna Creek Unit #42-O5Y ( Swanson River I CHEVRON CORPORATION ~;,;~~.~QOy#13Q7 D2t+~ T~111B ~`r~ng C(~Pt` FiA'FE i.ie~is#y G~t' STC Vi1L ~1i~UAL 0 0~ ~SSi1t~ ~~~- ~ ~ ~+ ~ a PIL'ffSUFE i~ c~ r/'~,>,Y- a ~~' : 24 hr ;~ 4~us~~ ~,~~~~ ~~~`~ .~~ ~ ~~ f ; i ` ~ ~~ ~ ,,, . . ` ~ ;', ! clock ps~ ~. Isbttinin' Ib1g~i "' bbE db} °; 0 G . a . : . ... ~ . . ~.,.... ,,,.~ ...:,...; . .. ..;, ..:. .-.-.,.... .,:.:. .., .;.:..,...: 2007-Aug-13 1.45 1987 ~ 2.7 8.42 I 255.9 484.2 0 ~ 0 - ' ~ 2007-Aug-13 1:46 - 2010 2.7 ~ 8.42 258.1 - - 486.4 I 0 l 0 2007-Aug-13 _. _---- -- 1:47 ' 2042 - 2.7 ---- -- 8.41 ------ - 260.3 --- _._._ -- ---- I 488.7 0 0 2007-Aug-13 1:48 ~ 2069 2.6 I 8.41 - - 262.6 ~ 490.9 0 0 - 2007-Aug-13 1:49 2092 2.7 ~ 8.41 264.8 , 493.1 ~ 0 0 2007-Aug-13 1:49 2110 2.6 8.41 267.0 495.3 0 _" 1_....__ 0 i -' 2007-Aug-13 1:50 2115 2.7 8.41 269.2 497.6 ~ 0 0 . 2007-Aug-13 1:51 2138 2.7 8.41 271.5 499.8 i 0 0 2007-Aug-13 1:52 2165 2.6 8.41 - 273.7 ------ _ ---. 502.0 0 0 2007-Aug-13 1:53 2202 2.6 8.42 - 275.9 -- ---... --- -------- 504.2 0 I 0 2007-Aug-13 1:54 2216 2.7 8.41 278.1 506.4 ~ 0 i 0 2007-Aug-13 1:54 2243 2.6 8.41 ~ 280.3 508.6 0 0 2007-Aug-13 1:55 2257 2.6 8.41 282.5 510.9 0 ~ 0 2007-Aug-13 1:56 2284 2.7 8.41 284.7 513.1 0 0 ~ 2007-Aug-13 1:57 2284 2.6 8.41 287.0 515.3 0 0 ~ 2007-Aug-13 1:57 ~ __ slow rate to 2 bpm 2007-Aug-13 1:57 2197 1.7 8.41 i 287.6 516.0 ; 0 0 2007-Aug-13 1:58 2119 - 1.7 8.41 288.5 516.8 ' 0 - 0 2007-Aug-13 1:59 2110 1.7 8.41 ~289.9 - --- --- i 518.2 0 _ ---- 0 2007-Aug-13 1:59 2119 1 J 8.41 291.3 ~ 519.6 0 0 2007-Aug-13 -- 2:00 2142 ----- 1.7 _---- - 8.41 --..-- 292.7 -- i 521.1 ` 0 ~---__ _ 0 2007-Aug-13 _ 2:01 -- 2147 1.7 8.41 294.1 ; ___ _ - 522.5 0 ~ ---''- 0 2007-Aug-13 2:02 2161 1.7 8.41 295.5 ' - 523.9 ' 0 i 0 -- --- 2007-Aug-13 2:03 2161 1.7 8.41 296.9 525.3 0 ! 0 ~ 2007-Aug-13 --- 2:04 2174 I 1.7 8.41 298.4 526.7 ~ 0 0 __ __ _ 2007-Aug-13 2:04 2147 1.7 8.41 -- 299.8 --- _. _.._ _--- 528.1 'I 0 0 - 2007-Aug-13 2:05 - - 2106 --- 1.7 8.41 301.2 T-- --- 529.5 i 0 L---- -- 0 - -- 2007-Aug-13 2:06 2101 1.7 8.41 302.6 530.9 ' 0 0 2007-Aug-13 2:07 __ 2078 _ _ 1.7 ---- 8.41 _.- 304.0 __ _-- 532.3 0 - 0 -- 2007-Aug-13 - ----- 2:08 --- 2083 1.7 8.41 305.4 533.7 0 - ~- 0 -- ---~ 2007-Aug-13 _ -- -- . - 2:09 - 2087 1.7 ~ 8.41 306.8 535.1 I 0 0 -- --- 2007-Aug-13 2:09 2083 1.7 8.41 308.2 536.5 ~ 0 0 2007-Aug-13 2:10 2074 1.7 8.41 ---- 309.6 - _ _ -- 537.9 i~ 0 0 - -- ~ 2007-Aug-13 2:11 2078 1.7 8.41 311.0 539.3 i 0 0 ~ 2007-Aug-13 2:12 ' 2074 1.7 8.41 312.4 - 540J 'i 0 --- --- -+--- 0 ____ ---- ---- ---- j 2007-Aug-13 2:13 2074 1.7 8.41 313.8 542.1 ' 0 0 2007-Aug-13 2:14 2078 1.7 ~ ~ 8.41 315.2 543.5 ~ 0 0 -- ' 2007-Aug-13 2:14 --- 1859 ------ 0.0 ! -- 8.41 --- 315.7 - _._ _._- 544.0 ~ 0 0 - i 2007-Aug-13 2:14 ! I displaced 308 bbls brine ; 2007-Aug-13 2:14 j 1836 0.0 ~ 8.41 315J 544.0 ~ 0 0 ~ ; 2007-Aug-13 2:15 - - _ __ --- - --- --- -------- ~ I i --- - with 1/2 shoe track ~ 2007-Aug-13 2:15~ 1826 - 0.0 8.41 315.7 544A l 0 ~ . 0 i ~ 2007-Aug-13 2:15 - --- - --- - ___ __ End Brine 2007-Aug-13 - - 2007-Aug-13 - - 2 15 215 - - 1772 -- - . 1739 ~ -- - 0.0 - --- 0.0 - -- 8.41 --- --- 8.41 - -- -- __ + 315 7 - 315.7 544.0 ~ 0 - --- - - 544.0 0 ~ - 0 0 - ~ - -- --- - -- - ~ 2007-Aug 13 2 15 1735 ~ 0.0 8.41 I 315 7 -- 544.0 0 0 -- I 2007-Au 13 2007-Aug-13 2 15 2.16 1726 ~ 0.0 8.41 ~ ~ 315 544.0 I~~T 0 ~0 Reset Sta e Total - 308.00 bbl g ~ 2007-Aug-13 _._..._ _ _- 2007-Aug-13 2:16 - 2:16 ~ - -~ 1607 ~ -- 0.0 8.41 , 315.7 - --- - -- 544.0 0 0 Top Plug did not bump ----- ~ - 2007-Aug-13 2:17 1451 i - 0.0 8.41 315.7 ~ -- --- ----- 544.0 0 ! 0 - ' - --- ---- __.._ ~ __ _ 2007-Aug-13 2:18 ~ 5 ~ ~ - T 0.0 8.41 315.7 r 544.0 , 0 ; 0 ~ 2007-Aug 13 - 2007-Aug-13 2:18 '~ - 2:18 ~ 5 i ___ '~ 0.0 8.41 -, 315 7 ~ -~ 544 0 0 0 _ _ _ _ ~ ~' - --- . .-- - bleed back and check floats 1 Aug 13,2007 WRS3 v3.414-SR Page 6 of 7 ~ ~ Well Field Service Date Customer Soldotna Creek Unit #42-05Y Swanson River CHEVRON CORPORATION 2007-Aug-13 2:18 I - -_- ---- - ' ~ + I 2 bbls back on check 2007-Aug-13 2:18 ', 0 0.0 8.41 -- --- --- 315J ; 544.0 -- 0 I 0 ---- i--- 2007-Aug-13 2:19 ~ 0 0.0 8.41 315.7 ~ 544.0 0 ~ 0 2007-AUg-13 2:19 j ~nd Job 2007-Aug-13 2:19 ~ 5 0.0 8.41 315.7 544.0 0 0 2007-Aug-13 2:19 ~ 0 0.0 8.41 0.0 544.0 0 0 ,. ' V~ ~~ Past .li~ks ~uenmary ~~ ~ ~ ~~, ~''~ Average Pump Rates, bpm Volume of Fluid Injected, bbl Slurry N2 Mud Maximum Rate Total Slurry Mud Spacer NZ 3 ---__ _. ~ ( _ - 4 192 I ~ 36.5 ~ Treating Pressure Sum mary, psi Breakdown Fluid Maximum Final Average Bump Plug to Breakdown Volume Density 5000 ~ 1800 0 bbl I Ib/gal Avg. N2 Percent Designed Slurry Volume Displacement Mix Water 7emp I~ Cement Circulated to Surface? Volume bfJl % ~_ 190 bbl 308 bbl °F j 75 L! Washed Thru Perts To ft CustomerorAuthorizedRepresentative Schlumberger __ Supervisor _ , BfBdfOfd, Jason Shane Wills i~ CirculationLost L~ Job Completed Aug 13,2007 WRS3 v3.414-SR Page 7 of 7 ~ ~ Operator : Chevron Country : USA State : Alaska Well : SC42-05Y Field : Swanson River Prepared for : Mrs. Chantal Walsh Location : Nabors 129 Proposal No. : Post Job Service Point : Kenai, AK Date Prepared : 8-8-07 Business Phone : 907-776-8156 FAX No. : 907-776-8158 Prepared by : Tony Stafford Phone : 907-273-1700 E-Mail . tstafford@anchorage.oilfield.slb.com well description Configurati Casing Stage : Single Rig Type : Land on Prev.String MD : 100.0 ft Csg/Liner MD : 3000.0 ft Landing Collar MD Casing/liner Shoe MD Mud Line Total MD BHST Bit Size Mean OH Diameter Mean Annular Excess Mean OH Equivalent Diameter Total OH Volume OD : 16 in OD:95/8in 2920.0 ft 3000.0 ft 0.0 ft 3000.0 ft 104 degF 12 1/4 in 12.250 in 50.0 % 13.371 in 503.6 bbl (including excess) Weight : 109.0 Ib/ft Weight : 47.0 Ib/ft Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the modef, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. or others is not to be inferred. Page 1 sc42-O5 post job.cfw ; OS-OS-2007 ; LoadCase Surface ; Version wcs-cem45_89 Client : Chevron r ~ Well : SC42-05Y ~ r ~ String : 9-5/8 District : Kenai, AK Country : USA Loadcase : Surface Section 1: fluid sequence Job Objectives: To achieve cement to surface. Original fluid Mud 9.30 Ib/gal k: 1.51 E-2 Ibf.s^n/ft2 n: 0.511 Tv : 3.50 Ibf/100ft2 Displacement Volume 213.8 bbl Total Volume 600.1 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology bbl ft ft Ib/ al Water 5.0 0.0 8.33 viscosity:5.000 cP MUDPUSH II 40.0 0.0 11.50 k:1.21E-2 fbf.s^n/ft2 n:0.517 Tv:2.88 Ibf/100ft2 Extended G 279.7 2333.3 12.80 k:9.21 E-2 Ibf.s^n/ft2 n:0.185 Tv:2.14 Ibf/100ft2 G cement 61.6 666.7 2333.3 15.80 k:2.13E-3 Ibf.s^n/ft2 n:0.988 Tv:33.15 Ibf/100ft2 Mud 213.8 0.0 9.30 k:1.51 E-2 Ibf.s^n/ft2 n:0.511 Tv:3.50 Ibf/100ft2 Page 2 sc42-OS post Job.cfw ; 08-OS-2007 ; LoadCase Surface ; Version wcs-cem45_89 • • Client : Well : Chevron SC42-05Y ~ ~~ String : 9-5/8 District : Kenai, AK Country : USA Loadcase : Surface Section 2: pumping schedule Start Job: Circulate two hole volumes, Safety Meeting, Test Surface Equipment Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. (degF) Comments Water 5.0 5.0 1.0 5.0 80 Water Ahead MUDPUSH II 5.0 40.0 8.0 40.0 80 MudPUSH Spacer Pause 0.0 0.0 5.0 0.0 80 Drop Bottom Plug Extended G 3.0 279.7 93.2 279.7 80 Lead Slurry G cement 5.0 61.6 12.3 61.6 80 Tail Slurry Pause 0.0 0.0 5.0 0.0 80 Drop Top Pfug Mud 7.0 200.0 28.6 200.0 80 Displacement Mud 2.0 13.8 6.9 213.8 80 Slow Rate to Bump Top Plug Total 02:40 600.1 bbl hr:mn End Job: Bump Plug, Bleed-Off PSI, Check floats. D namic Security Checks : Frac 3 psi at 100.0 ft Pore 2 psi at 107.7 ft Collapse 3999 psi at 2920.0 ft Burst 6170 psi at 0.0 ft Temperature Results BHCT 92 degF Simulated Max HGT 104 degF Simulated BHCT 85 degF Max HCT Depth 3000.0 ft CT at TOC 84 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures : At Time 00:20 hr:mn (hr:mn) Geo. Temp. Top of Cement (degF) (degF) ~ 80 degF Bottom Hole (degF) (degF) 104 degF Page 3 sc42-O5 post job.cfw ; 08-08-2007 ; LoadCase Surface ; Version wcs-cem45_89 Client : Chevron • • Well : SC42-05Y String : 9-5/8 District : Kenai, AK Country : USA Loadcase : Surface ~ ~ ~ Section 3: centralizer placement Top of centralization :100.0 ft Bottom Cent. MD :2980.0 ft Casing Shoe :3000.0 ft NB of Cent. Used :21 NB of Floating Cent. :21 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth ft Joint (%) ft) 2880.0 18 1/4 HOWCO DUAL 100.0 2860.0 3000.0 3 1/1 HOWCO DUAL 100.0 3000.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) HOWCO DUAL 9 5/8 12.625 11.250 No HOWCO 12.250 246.00 4765.00 (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 4 sc42-OS post job.cfw ; 08-OS-2007 ; LoadCase Surface ; Version wcs-cem45_89 Client : Chevron Well : SC42-05Y String : 9-5/8 District : Kenai, AK Country : USA Loadcase : Surface • ~ ~~ ~~~~'' sc42-05 post job.cfw ; 08-OS-2007 ; LoadCase Surface ; Version wcs-cem45_89 Page 5 Client : Chevron ~ • Well : SC42-05Y I ~ ~~ String : 9-5/8 District : Kenai, AK Country : USA Loadcase : Surface * CemCADE Client : Che~ron Well SC42-OSY String 9-5/8" Surtace Casing District Kenai, AK Country : USA v M N N ~ Q N 3 ~ N ~ N N a ~ ~ Qo rn ~ 0 50 100 150 200 Time (min) Total Depth = 3000.0 ft Top of Cement = 0.0 ft v M N m Q N N~ 7 y N N a`~ ~ ~ Q 0 rn w Depth = 3000 ft 0 40 80 120 160 200 Time (min) 'Mark of Schlumberger Page 6 sc42-05 post job.cfw ; OS-OB-2007 ; LoadCase Surface ; Version wcs-cem45_89 ~ • Client : Well : Chevron SC42-05Y n ~~ String : 9-5/8 District : Kenai, AK Country : USA Loadcase : Surface Section 4: fluid description Mud DESIGN Fluid No: 1 Density : 9.30 Ib/gal Rheo. Model ; HERSCHEL B. k : 1.51 E-2 Ibf.s^n/ft2 At temp. : 80 degF n : 0.511 Ty :3.501bf/100ft2 Gel Strength : 4.56 Ibf/100ft2 MUD Mud Type : WBM Job volume : 213.8 bbl Water Type : Fresh VOLUME FRACTION Solids : 8.0 % Oil : 0.0 % Water : 92.0 % MUDPUSH II DESIGN Fluid No: 3 Density : 11.50 Ib/gal Rheo. Model : HERSCHEL B. k : 1.21 E-2 Ibf.s^n/ft2 At temp. : 80 degF n : 0.517 Ty :2.881bf/100ft2 Gel Strength : 17.09 Ibf/100ft2 Job volume : 40.0 bbl Lead Slurry Extended G DESIGN Fluid No: 4 Rheo. Model : HERSCHEL B. At temp. : 80 degF Density k n Ty Gel Strength DESIGN BLEND SLURRY Name : G Mix Fluid : 11.064 gal/sk Dry Density : 199.77 Ib/ft3 Yield : 1.97 ft3/sk Sack Weight : 94 Ib Porosity : 75.1 % BASE FLUID Type : Fresh water Density : 8.32 Ib/gal Additives Code Conc. Function D079 1.500 %BWOC extender D046 0.200 °/aBWOC antifoam S002 1.000 %BWOC accelerator Thickening Time Schedule () 70 Bc Compressive Strength Schedule ( ) (psi) 12.80 Ib/gal 9.21 E-2 Ibf.s^n/ft2 0.185 2.14 Ibf/100ft2 (Ibf/100ft2) Job volume : 279.7 bbl Quantity : 797.34 sk Solid Fraction : 24.9 % Base Fluid : 11.064 gal/sk at 06:20 hr:mn at (hr:mn) Page 7 sc42-O5 post job.cfw ; OS-08-2007 ; LoadCase Surface ; Version wcs-cem45_89 ~ • Client : Chevron Well : SC42-05Y ~ ~~ String : 9-5/8 District : Kenai, AK Country : USA Loadcase : Surface G Tail cement DESIGN Fluid No: 5 Density : 15.80 Ib/gal Rheo. Model : HERSCHEL B. k : 2.13E-3 Ibf.s^n/ft2 At temp. : 80 degF n : 0.988 Tv :33.151bf/100ff2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water SLURRY Mix Fluid : 5.102 gal/sk Yield : 1.16 ft3/sk Porosity : 58.6 % Density :8.321b/gal Code Additives Conc. Function D065 0.300 %BWOC dispersant D046 0.200 %BWOC antifoam D167 0.300 %BWOC fluid loss S002 0.100 %BWOC acceierafor D153 0.200 %BWOC antisettlin Job volume : 61.6 bbl Quantity : 297.51 sk Solid Fraction : 41.4 % Base Fluid : 5.102 gal/sk Thickening Time Schedule 9.6-1 100 Bc at 03:16 hr:mn Compressive Strength Schedule ( ) (psi) at (hr:mn) Water DESIGN Fluid No: 6 Density : 8.33 Ib/gal Rheo. Modei : NEWTONIAN At temp. :(degF) Viscosiry : 5.000 cP Gel Strength : (Ibf/100ft2) Job volume : 5.0 bbl Page 8 sc42-O5 post job.cfw ; 08-OS-2007 ; LoadCase Surface ; Version wcs-cem45_89 .~ ~ _ a o~--o~a I4.* C~ICAL iI~tTEGRITY ~L.PORT ~ ~ - - _ ~UD u::=~ : : ~~t'~~0~ -- QPEt2 ~ FIEI.~J C.~`~c.vCO~ SWG`~r~~`CC- :=G r~.~~r.,... - ~/ap-p'Z h:..I.L NUMEER SCV ~~-OS~ ~ SaS S~o c'c~.SS'c n ~ LL ~~:T ~_ ~n : ~~~ 0 .~.. Ss l~-1 ~ ~-vD ; _ ~TD : ~01 ~ ~ "~~,4(,~ Casi~g : ~ ~ Shoe :~~~`~ tID c6C~a TVD ~ i-it : N A- :~ UI~ -'~'4~ -_:~e= . l`1Q ~hae. '~ ?'`J~; w~P . -'_-~ `;~ =;~o'~~ • 3~1a ?acicer `t`15~ ?~D T`~i ; ~et ~~~~50~ :ole S.:.~e ~S t I~ ~nd ; t er~.~ 'ZS6~'~. ~ ~o `Z~~o~ ~,'i,'r'.~?~?r~.~. ~ tITEG~?'T~Y - PA~tT # i cn~u~us ?.~ess Test: ~~ ;~5 nin ;:~0 min Coc~e:~t~ : ~J~~r. ~t r \ s~~ ~ ~~ l~~v~~r C01t~-C `~~~ . ~ '~ CHP N i Cri, i NTEGRI'?'~' - PAR'I' # Z Ce~ent Vol~es : r~~mt. ~iner ~ CsQ ; I?V C.j,~ ~ro~ to cflver ~er=~ ~' 30~2oXS aa b~`s Ncvc.SSC~~ ~ ~ T ~-o p p~ ~- p~~c~ '~~ ~ _ _e~retical 'T~C ~ 30 ~,S~U, `2n ~6..5 ~" s o w~\~oS~- ~~ _ , ~~V ~~ ts~ ~ ~~c~~ N ~~~~ Cement Bond Log (Yes or No) ~~~ _; In AOGCC File CBL ~valuatian, ~one aoove per~s ~,,~~,c~~ a~~ ~Jo~~h Proauctian Z.og : Type ; Evaluat~on ~O~~LJS~OtdS : ?art #l. ?ar~ i2: ~' Y ~' l ``~' ~~-O`1 ~~~~ ~ . ~ ~ ~~~~rr~r~ ~ ~ ~ 91~9 i~. ~~ ~venue Anchorage, Ak 99541 907263.7870 SHIP TO: AOGCC Arin: Howard Okland 333 W. '7th Avenue Anchorage, AK 99541 907.793.1223 CONTENTS• Wasli/Dried Cutting Samples Company Well Field Region: Coordinates Elevation CountyiState API Index Spud T~ate TD Date TD Depth Chevron USA, Inc SCU 42-OSY Soldotna Lreek Unit Kenai Peninsula 197~' ~NL, 439' FEL Sec. 5 T7N R9W SM kt~ 1 ~3.~0 Feet GL 156.04 Feet Kenai Borough, Alaska 50-133-20570-00-00 July 1'7, 2007 »> »> »»TVD Chevron Ueologist: Khristina Kirschner Total Boxes 5 Sample Interval 30 foot samples Fi1000 T/ 8110 feet NID 10 foot samples F/ 7800 T/7890 feet MD SAMPLES PROCESSED BY: Epoch Well Services 301 East 92na Avenue Anchora~e, AK 99515 907.561.24b5 Mud Lo~~ers Andrew O'Fallon, Larry Resch 5ample l;atchers kick Frederick, Nick Moir ~ 1 1 ~~ "" ~~~ Chevron Debra Oudean Chevron North Amei"~'a Exploration and Production Techical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7889 ~ Fax: 907 263 7828 E-mail: oudeand@chevron.com October 12, 2007 ~ ~ ~ ; ~ ~ ~: ~~ ~ ~ ~~ '. ~, ~ ~.~ _~.~ ,~ 1 i jv ., ? . To: AOGCC ~~~° ; ,~ ~~~, Howard Okland ~ '' ~ 333 W. 7t" Ave. Ste#100 Y,~,~~ v,~~ 3~, ,;;:,,,y~s ~ Anchorage, AK 99501 ~ a,y~r~~~~ ~ '"$. .~~r 'F-."^o°~'~~ 'x..~r't,.~" ~~ r, ~.3 ~`"~+.~'~ z~ v~ti, ' s ~ ~ -~ '#`9~ ~ ."' ~` ~ 1. p ;~- ~ 1 ,±TeS~, ~~ ~ W"` ~i ~sn~y X t'~. tAi -~r ?~Y" ~'~ r~( ~ S~ ~~, k .3 k *~+~.`^ a~ aa~` x,, ~~ " ky s 'i Y t~S,, . ~ a~ x~~', '~ ~ g,"~' .v~e,~~ 5 ~~ i~ 1 .~`sE '.. ~''a'~.' s . +~`3~. `'~~ ~" ~``x : ~ i+.~tFS` v~ ~ "~`~--._,_. 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EVALUATION USIT I GR l CCL .._ ___ W ......_~_~._...__ _.__ ._..... . _._-_ .__..__ ~ . ._ ~~_.. . _; ___ __,_ ~ __ ~ ____ _.~. ~... ._ 501332057000 . __~ SCU 42-05Y ' MULTIPLE PROPAGATION 2 8/11/07 297-8110 1 ' 1 ; i RESISTIVITY ( NEUTRON ~ ~ ~ .__._._.. __ . .. POROSITY / BULK DENSITY I ! GAMMA RAY ND .._.___.__. .__._____ _____. ....___ _..__.__ __~___ ..._..._ .~..__ __ _,__ __.. ____ . ___.. _ ' ___.._. __. 501332057000 _ _ _ SCU 42-05Y MULTIPIE PROPAGATIUN 5 8/11/07 297-8110 1' 1 i , RESISTIVITY / NEUTRON , ~ POROSITY ! BULK DENSITY / , GAMMA RAY ND ; _ . ~ _._ _ ~ 501332057000 __ __ _...._ SCU 42-05Y . , .___ ___..__ .. _ MULTIPLE PROPAGATION 2 8/11/07 _ _....... 297-8110 1 _.,.. 1 ~ RESISTIVITY / NEUTRON i ~ POROSfTY / BULK DENSITY / I ; -- ; _ __~.. ____~_ 501332057000 ' __._._.__._.___ ____ SCU 42-05Y GAMMA RAY MD ._._.~_~~ ._ ___..---_ .____ .__ ____._ MULTIPLE PROPAGATION ` __.._,._ 5 _.____ 8/11/07 _____.___ 297-8110 _ 1 __ _ 1 _._-- ~.. .._._ ._ . . __. _ ._-! ~ ~ , RESISTIVITY ( NEUTRON ; POROSITY / BUIK DENSITY / ' ' ~ . _ _ __._. _.. __ _ GAMMA RAY MD . _. __ _..._...._._ _._...~.. _ __ ...._._.._ _ . ., . . ..,. . _ . __. _ __ ~ .. . _ . _. . ~ 501332057000 _ - SCU 42-05Y EPOCH FINAL WELL DATA 1 ~ ~ DML DATA j ' FINAL WELL REPORT i ; LAS FILES ( ~ LOG PDF FILES j i MORNING REPORTS ; ~ SAMPLE MANIFEST _ __ . _ _. , ^,` 501332057000 ___ SCU 42-05Y DIRECTIONAL DRILLING END 1 ~ PDF i ~ ' OF WELL REPORT _ . _____._ _ ._. . .. __ _ _.__.! use ~~--o~sa ~ r~ ~- Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: . ~ I~~~ ~ , ~I~ 'V z TRUE Oil ~ Gas ~ Plugged ~ Abandoned ~ Suspended ~ ~=~e,~~'~ e~S~ 20AAC 25.105 20AAC 25.110 GINJ ^~ WINJ ^ WDSPL^ WAG ^ Other^ No. of Completions: ~. 1 b. Well Class: ~?~~C 'xp~~~p Development ^ Exploratory ^ ervice ^~ Stratigraphic Test^ 2. Operator Name: Union Oil Company of California 5. Date Comp., Susp., or/~ Aband.: 8/28/2007 12. Permit to Drill Number: 207-082 3. Address: PO Box 196247, Anch, AK 99519 6. Date Spudded: 7/17/2007 13. API Number: 50 133 20570 00 00 4a. Location of Well (Governmental Section): Surface: 431' FEL, 3283' FNL Sec 5, T7N, R9W, SM 7. Date TD Reached: 8/11/2007 14. Well Name and Number: SCU 42-05Y Top of Productive Horizon: 455' FEL, 2726 FNL, Sec 5, T7N, R9W SM 8. KB (ft above MSL): 16.77 Ground (ft MSL): 0' 15. Field/Pool(s): Total Depth: 450' FEL, 2711 FNL, Sec 5, T7N, R9W, SM 9. Plug Back Depth(MD+TVD): 8014' / 7946 Swanson River Field 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 341876 y- 2457938 Zone- ~ 10. Total Depth (MD + TVD): 8110' / 8041' 16. Property Designation: A028996 TPI: x- 341844 y- 2458520 Zone- Total Depth: x- 341849' y- 2458528' Zone- 11. SSSV Depth (MD + T~/D): None 17. Land Use Permit: n/a 18. Directional Survey: Yes ~ No (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: n/a (ft MSL) 20. Thickness of Permafrost (ND): n/a 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): USIT, LWD - GR-RES- Neutron Density (logs will be sent under separate cover) 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTfOM TOP BOTTOM pULLED 16" 109 K-55 0 96' 0 96' Drive None 9-5/8" 47 L-80 0 3054 0 3054 12.25" 341.3 bbls G-neat None 7" 26# L-80 0 8097' 0 8029' 8.5" 192 bbls Flexstone None 23. Open to production or injection? Yes Q No ~ If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 77-3 Sand: 7846' - 7864' (7778' - 7796' ND) 4-5/8" TCP Guns @5 spf 3.5" 7809' 7754' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED None 26. PRODUCTION TEST Date First Production: ei28i2oo~ Method of Operation (Flowing, gas lift, etc.): Flowin Date of Test: 8/28/2007 Hours Tested: 1/1/1900 Production for Test Period Oil-Bbl: 0 Gas-MCF: 0.25 Water-Bbl: 0 Choke Size: 20-64 Gas-Oil Ratio: n/a Flow Tubing Press. 3551 Casing Press: 150 Calculated 24-Hour Rate -• Oil-Bbl: 0 Gas-MCF: 6 Water-Bbl: 0 Oil Gravity - API (corr): n/a 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No 0 Sidewall Cores Acquired? Yes ^ No 0 If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. n/a I C0,"~;P~E7a0N ~' ~~~ F c~ . ~ - ~-~ . _ , - - - , Form 10-407 Revised 2/2007 ~~~~~~~C~ TINUED ON REVERSE L - ~ ~ ~ , STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~~I~~ ~~~ ~ ,~ ~~~7 WELL COMPLETION OR RECOMPLETION REPOR~~i~N~L~~~. C~mmissia~ ~ 1 t ~ ~ 28. 'GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD Tl/D Well tested? ^ Yes ~ y No If es, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Beluga Formation 3345' 3344' needed, and submit detailed test information per 20 AAC 25.071. Tyonek 5405' 5396' Formation at total depth: 30. List of Attachments: Operations summaries, Schematic, Final Directional Data 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Chantal Walsh 263-7627 Printed Name: Lar B a r ~ Title: Engineering Manager Signatur . Phone: 263-7853 Date: 9/27/2007 [I~~~:Z1Z~~L~I`iE-~ 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 / 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 and Ground Level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 thev~t+~n ` - Chevron - Alaska ~ Daily Operations Summary Well Name SCU 42-05Y Field Name Soldotna Creek API/UWI 50-133-20570-00 Lease/Serial A020896 Orig KB Elev (ftKB) 20.5 Water Depth (ft) Primary JobType Drilling - Original Primary Wellbore Affected Original Hole Jobs Primary Job Type Drilling - Original Job Category Drill AFE No. S7000 Objective Drill gas storage service well to Tyonek 77-3 sand. Actual Start 7/10/2007 End Date QC Engineer I ' Daily Operations 6/18/2007 00:00 - 6/19/2007 00:00 Operetions Summary SIMOPS. Prep location for placement of conductor pipe. 6/19/2007 00:00 - 6/20/2007 00:00 Operetions Summary --- --''. SIMOPS. Continue work on cellar and conductor pipe. ' 6/20/2007 00:00 - 6/21/2007 00:00 -~ Operations Summary `-- ~ SIMOPS. PJSM. Prep location. 'i 6/21/2007 00:00 - 6/22/2007 00:00 ' Operations Summary ~ SIMOPS. PJSM. Prep location. I 6/22/2007 00:00 - 6/23/2007 00:00 -~i Operations Summary SIMOPS. PJSM. Prep location. 6/25/2007 00:00 - 6/26/2007 00:00 Operations Summary ------- ------- - SIMOPS. PJSM. Prep location. 6/26/2007 06:00 - 6/27/2007 00:00 OperationsSummary ---- ----- ------------- ----- SIMOPS. PJSM. Prep location. 6/27/2007 00:00 - 6/28/2007 00:00 Operetions Summary ' SIMOPS. PJSM. Prep location. 7/8/2007 00:00 - 7/9/2007 00:00 Operetions Summary ' SIMOPS. PJSM. Prep location. 7/9/2007 00:00 - 7/10/2007 00:00 Operations Summary SIMOPS. PJSM. Prep location. - --- --- 7/10/2007 00:00 - 7/11/2007 00:00 Operations Summary SIMOPS. PJSM. Prep location. 7/11/2007 00:00 - 7/12/2007 00:00 Operations Summary ~ SIMOPS. PJSM. Prep location. 7/12/2007 00:00 - 7/13/2007 00:00 Operations Summary SIMOPS. PJSM. Mobe rig. 7/93/2007 00:00 - 7/14/2007 00:00 Operations Summary SIMOPS. PJSM. Mobe rig. 7/14/2007 00:00 - 7/15/2007 00:00 Operations Summary SIMOPS. PJSM. Mobe rig. 7/14/2007 00:00 - 7/15/2007 00:00 Operations Summary SIMOPS. PJSM. Mobe rig. 7/15/2007 00:00 - 7/16/2007 00:00 Operations Summary SIMOPS. PJSM. Mobe rig. 7/16/2007 00:00 - 7/17/2007 00:00 Operations Summary Pre tower safety meeting with drilling crews. Function tested the diverter system with AOGCC witness. Recorded closure time as 18 sec, and open time as 1 min 25 sec. A pre-job safety meeting was held with all personnel on location. ~ r~ ~Ghev~on` Chevron - Alaska ~ Daily Operations Summary Well Name SCU 42-05Y Field Name Soldotna Creek APIlUWI Lease/Serial 50-133-20570-00 A020896 Orig KB Elev (ftK6) 20.5 Water Depth (ft) Daily Operations 7/17/2007 00:00 - 7/18/2007 00:00 Operations Summary Pre job safety meeting with all service hands. P/U BHA and spud well at 9:OOAM. Rotary drill to 297 ft. TOOH. Lay down BHA. PJSM. PU and rack back drill pipe. Mud Wgt = 9.Oppg 7/18/2007 00:00 - 7/19/2007 00:00 Operatians Summary Finish racking back drill pipe. PU bit, directional BHA, MWD and LWD tools. Drill from 297' to 1300' (slide from 590 - 620). Mud wt. is 9.1 ppg. Held safety meetings. Operationally started the G&I plant. 7/19/2007 00:00 - 7/20/2007 00:00 Operations Summary - - --- Drilled from 1342' to 2241'. Continued drilling to 2985' (slide from 2888' to 2925'). Reamed each stand drilled. ADEC was notified via email of Start of Operations at the G&I facility. Mud Wgt = 9.7ppg 7/20/2007 00:00 - 7/21/2007 00:00 Operations Summary Drill from 2985' - 3000'. Circulate and condition hole. Rotate/reciprocate pipe. TOOH. Circulate and condition hole, TIH. Drill 3000' - 3060'. Condition mud. Pump nutplug marker. TOOH. LD BHA. PTSM on PU casing tools, laying out BHA, tripping, wellcontrol and LD BHA. SIMOPS. Mud Wgt = 9.9PP9 7/21 /2007 00:00 - 7/22/2007 00:00 Operetions Summary Finish LD BHA. MU hanger and landing joint. PU 75 jts of 9-5/8" 47#, L80, Mod Buttress Csg. Shoe set at 3054, float collar at 2971. 21 Centralizers placed. 1 each on the bottom 3 JTS and 1 every 4th to 10 '. Circulate, cemen equipmen . . cemen ines, drop ottom plug, m bbl lead slur , 61.6 bbls tail drop top plug, bump plug, hold ressure at 3000 si for 30 mins. PTSM on running casing, casing handling hazards, cementing hazards and rnpp e down operations. SIMOP wit pro uction. u g= . ppg 7/22/2007 00:00 - 7/23/2007 00:00 Operations Summary ~ RD cementers. Nipple down diverter system. Nipple up BOPE. Held Safety stand down. PTSM on driving safety, nipple up operations. SIMOPS with production. 7/23/2007 00:00 - 7/24/2007 00:00 Operations Summary Install 2-7/8" - 5" VBR in top BOP, blind rams in middle, 4" pipe rams in lower. Test BOPE with AOGCC as witness. Test 250 low and 5000 hiqh. SIMOPS with production. PTSM on BOP testing, current operations and hazard identification. 7/24/2007 00:00 - 7/25/2007 00:00 Operations Summary Finish BOP testing. PU and install wear bushing. PU and trip in open ended 78 jts of 4" drillpipe. Ran "shut in and kill/choke drill with crew. Circulate and condition mud. Trip pipe. PTSM on picking up BHA and source for LWD. 7/25/2007 00:00 - 7/26/2007 00:00 Operations Summary --- PU BHA with 8-1/2" bit and motor. Set into top plug at 2970' and begin drilling out cement and float equipment. Drill out to shoe at 3056'. pljlll]e1oC. formation from to 3080' for FIT. Circulate bottoms up . PJSM. MU test lines and pressure test to 1500 psi. Shut lower pipe rams and begin formation integnty test. o leak off seen. EMW = 16 ppq. Shut in and bleed down. Bleed off pressure and RD lines. Drill from 3080' to 3669' (slide from 3573' - 3593'). Hole in good shape. PTSM on safety around shakers, mixing mud, and running FIT. SIMOPS with production. Mud Wgt = 9.4ppg 7/26/2007 00:00 - 7/27/2007 00:00 Operations Summary Drilled from 3669' to 5044' (slide 4532' - 52', 4729'-49', 4826' - 66', 4922' - 47' and 5018' - 44') PTSM on snub lines, tongs, PPE. SIMOPS with production. Recovered 6.25 oz of inetal shavinqs. Mud Wgt = 9.15ppg 7/27/2007 00:00 - 7/28/2007 00:00 Operations Summary Drill and slide from 5050' to 5504'. Circulate and condition ho(e. Pump piil. POOH as ~er BLM to chanae Dp around. Racked back lower portion of the drillstring and ran back in hole with new drillpipe on bottom. Circ B/U Gas 652 units B/U and Loads of cuttings. Drill and slide from 5504' - 5522'. PTSM on plan forward, tripping pipe practices and tong hazards. SIMOPS with production. No shavinas collected. Mud Wgt = 9.2ppg 7/28/2007 00:00 - 7/29/2007 00:00 Operations Summary Drill and slide from 5522' to 5939'. Unable to make footage, increased mud weight to 11 ppm. TOOH to check BHA. Minimal metal shavings on ditch ma nets - 0 oz on scale. PTSM on weighting up mud, proper procedure for handling radioactive source. SIMOPS with production. Mud Wgt = 10.2ppg r~ ~ ~Chevron ` Chevron - Alaska ~ Daily Operations Summary Well Name Field Name API/UWI Lease/Serial Orig KB Elev (ftK6) Water Depth (ft) SCU 42-05Y Soldotna Creek 50-133-20570-00 A020896 20.5 Daily Operations 7/29/2007 00:00 - 7/30/2007 00:00 Operations Summary Continue to LD BHA for motor and bit change a(bit cored). TIH w/ New Motor & Bit and test MWD. Wash to BTM No Fill. CBU and break in bit on bottom. Drill and slide from,5939 to 6106'. Weighted up mud to 12.4 by EOT. PTSM on mixing chemicals, housekeeping, and moving casing. SIMOPS with production. Metal shavinqs neqliqible for 24 hour period. Mud Wgt = 11.1 ppg 7/30/2007 00:00 - 7/31/2007 00:00 ^ ~ Operations Summary ' Drill and slide from 6105' to 6444'. Having trouble controling Slide Toolface. Circulate and condition, Pump Slug and TOOH. SIMOPS with production. PTSM on staying focused, and weighting up while drilling.ERecovered no metal shavinqs. Mud Wgt = 12.4ppg 7/31/2007 00:00 - 8/1/2007 00:00 ' Operations Summary - ----- Continue to TOOH. Change PDC bit for button bit for directional control. Changed out part of the LWD tool. TIH to 6372'. CBU. Rotate drill from 6444' to 6469'. Held a good slide, and had problems after slide. PTSM on handling nuclear sources, proper PPE, handling of materials going to G&I. Recovered no metal shavings. Mud Wgt = 12.4ppg 8/7/2007 00:00 - 8/2/2007 00:00 Operetions Summary Drilling and sliding from 6470' to 6660'. Lost pulse from BHA. POOH. SB HWDP. LD MWD and mud motor. PU directional tools and orient, load MWD. PTSM on handling BHA and housekeeping. SIMOPS with production. Recovered no metal shavings. Mud Wgt = 12.45ppg 8/2/2007 00:00 - 8/3/2007 00:00 Operetions Summary ----- ----- PU BHA and trip in hole. Test MWD. Drill from 6660' to 6678'. MWD lost pulse. POOH with drill pipe. LD BHA. Pick up MWD (directional only) tool. PTSM with crews on PPE, policing location, and handling BHA. SIMOPS with production. Recovered no metal shavings. Mud Wgt = 12.25ppg 8/3/2007 00:00 - 8/4/2007 00:00 Operations Summary PU BHA and surface test MWD. RIH and test MWD at shoe. Drill from 6,678 - 6,891'. SIMOPS with production. PTSM on unloading trucks and up coming gas zones and effect on pit gain. Mud Wgt = 12.4ppg 8/4/2007 00:00 - 8/5/2007 00:00 ~ Operations Summary Drill from 6,891' to 7,370', sliding 10' - 15' per stand to bring well to vertical. PTSM to discuss up coming cementjob, backing vehicles, and handling chemicals. SIMOPS with production. Mud Wgt = 12.4ppg 8/5/2007 00:00 - 8/6/2007 00:00 Operations Summary Directionally drill from 7,370' to 7,805'. CBU and mix dry job. Contacted AOGCC about upcoming BOP test, contacted BLM about upcoming 9-5/8" casing test. SIMOPS with production. PTSM about containment, mentonng new hands, and testing BOP procedures. Mud Wgt = 12.4ppg 8/6/2007 00:00 - 8/7/2007 00:00 Operations Summary Pumped dry job. POOH. LD BHA. Recover wear bushing and run test plud. Test rams to 250 si low and 5000 si hi h. Test annular to 250 psi low and 3500 psi high. All tested OK. Pull test plug and run wear ring. PU RTTS and run in o e. M P with production. TSM on staying focused, and weighting up while drilling. Mud Wgt = 12.5ppg 8/7/2007 00:00 - 8/8/2007 00:00 Operations Summary RIH with RTTS acker and set same at 2995'. Pressure test 9-5/8" surface casing to 1750 psi for 15 minutes. Release packer and trip out of hole. LD R7TS packer. PU LWD/MWD B . np in hole to 75 . og open o e wi oo s rom o . PTSM on proper PPE, handling of materials going to G&I. Mud Wgt = 12.55ppg 8/8/2007 00:00 - 8/9/2007 00:00 Operations Summary Finish Open Hole Logging W/ LWD to 7805', Drill F/ 7805' T/ 7876'. Mud Wgt = 12.4ppg 8/9/2007 00:00 - 8/10/2007 00:00 Operations Summary Drill 7876' - 8040', Repair #2 Mud Pump, Troubleshoot Top Drive Failure. Mud Wgt = 12.45ppg 8/10/2007 00:00 - 8/11/2007 00:00 Operations Summary Finish repair on TD and MP#2, TIH, W/R to TD at 8040', Drill 8040'-8085", Circ and work pipe, Repair MP#1. Mud Wgt = 12.4ppg ~Chevron` - ~ Chevron - Alaska ~ Daily Operations Summary Well Name SCU 42-05Y Field Name Soldotna Creek API/UWI 50-133-20570-00 Lease/Serial A020896 Orig KB Elev (ftK6) 20.5 Water Depth (ft) Daily Operations 8/11/2007 00:00 - 8/12/2007 00:00 OperaSions Summary - Finish Drilling to FINAL TD of 8110', TOOH, LD BHA, C/O Rams to 7" CSG Rams and Test, Test run Hanger, RU CSG Tools, Start Running 7" CSG. Mud Wgt = 12.4ppg 8/12/2007 00:00 - 8/13/2007 00:00 Operations Summary Finish Running 7" CSG, land,_Break Circ w/ No Returns, RU CMT head, RU cement equipment, Mix mud push, Batch mix cement, Press Test CMT lines, start cementing operations 8/13/2007 00:00 - 8/14/2007 00:00 Operations Summary Finish CMT 7" CSG. Pumped 192 bbls of Flexstone Cmt, install P/O and test, C/O Rams and Test, install W/B, T!H w/ 6" bit, Drill CMT, Clean Pits, WOC 8/14/2007 00:00 - 8/15/2007 00:00 OperetionsSummary --- - Circulate and clean out mud system. TOOH with clean out assembly and stand back DP. PUMU logging tools. RIH with USIT to 7995', loa up to 2400'. TOC at 3265'. POOH with tools. SIMOPS with production. Safety meeting on logging tools and mixing fluids. 8/15/2007 00:00 - 8/16/2007 00:00 Operations Summary ~ POOH with USIT log. RD eline. Pressure test the 7" casing to 5000# for 30 minutes. MU and run 6" bit, and scg scraper to 8014'. Displace fluid with 6% KCL mixed with 1% CRW -132. POOH and lay down DP. PU and set TCP gun. SIMOPS with production. Safety meeting with crews to discuss running completion equipment. 8/i 6/2007 00:00 - 8/17/2007 00:00 Operations Summary MU packer assembly, sliding sleeve, install RA tag. RIH with 3-1/2" 9.2# TCII connection tubing. MU chem. inj line. Continue to run completion to depth. RU eline. Correlate TCP depth for perforations. 8/17/2007 00:00 - 8/18/2007 00:00 Operations Summary POOH with GR-CCL, RD. RU wireline. RIH and set plug in profile at 7702'. Test tb to 5000# and chart. RIH and retrieve plug. POOH with plug and RD eline. Set BPV. Begin ND of all BOPE. NU wellhead tree and test to 50 . 8/18/2007 00:00 - 8/19/2007 00:00 Operations Summary RU wireline. RIH and set plug in ZN nipple at 7767'. POOH. Pressure test lu to 1000 si and set acker with 3500 si., hold for 30 min. Test 7" x 3-1/2" annulus acker and wellhead to 5000 si for 30 mins. Test witnessed by state. s ic ine. an retrieve p ug. RD slickline. Pressure up on chem ing line and burst disc @5000psi with diesel. elease rig. Demobe rig. 8/19/2007 00:00 - 8/20/2007 00:00 Operations Summary RD backend, Finish RD derrick, LD derrick, RD pumps, boiler, generators, doghouse, sub. All loads off rig matting @19:00. 8/20/2007 00:00 - 8/21/2007 00:00 ~ Operations Summary Demobe rig. 8/21 /2007 00:00 - 8/22/2007 00:00 ~ Operations Summary Demobe rig. 8/22/2007 00:00 - 8/23/2007 00:00 Operations Summary Demobe rig. 8/24/2007 00:00 - 8/25/2007 00:00 Operations Summary Clean location. 8/25/2007 00:00 - 8/26/2007 00:00 Operetions Summary ~ Finalized demobe. Prep location for production. 8/27/2007 00:00 - 8/28/2007 00:00 Operations Summary SIMOPS. RU slickline. RIH with shifting tool and open sliding sleeve at 7707'. POOH. Pump diesel down tubing while taking returns from annulus. RD slickline. thev~on` ~ ~ Chevron - Alaska ~ Daily Operations Summary Well Name SCU 42-05Y Field Name Soldotna Creek API/UWI 50-133-20570-00 Lease/Serial A020896 Orig KB Elev (ftK8) 20.5 Water Depth (ft) Daily Operations 8/28/2007 00:00 - 8/29/2007 00:00 Operations Summary SIMOPS and PJSM. RU Slickline. Dis lace fluid from tubin with as. -Ta fiuid level at 7366' RKB with final tubin ressure 3800 si.: RIH with 2.5" shifting tool. RIH and shift sliding sleeve o c ose . oa gun rop bar in u ncator. ressured tbg to 3 10 psi. roppe ar. e TCP guns go off. P~rforated the Tvonek 77-3 sand from 7846' to 7864'MD. 8/29/2007 00:00 - 8/30/2007 00:00 Operations Summary ~ ~ Chevron ~ Wellbore Schematic: SCU 42-05Y Final 9/23/07 Well Name: SCU 42-05Y Operator: Union Oil Company of California Field: Swanson River Unit: Soldotna Creek API: 50-133-20570-00 Permit: 207-082 Well Status: Gas Storage RKB: 16.77' above GL TD/TVD: 8,110 MD/8,042' ND PBTD/PBND: 8014' (drilled cmt to float collar) Casin Detail Size Wt Grade Type Top (FT) Btm (FT) Length (FT) 16" 109# K-55 0.00 96 96 9-5/8" 47# L-80 BTC 0.00 3,054 3,054 7" 26# L-80 TC-2 0.00 8,097 8,097 Tubin Detail Size Wt Grade Type Top (FT) Btm (FT) Length (FT) 3-1/2" 9.2# L-80 Atlas Bradford TC-2 0.00 7,809 7,809 Jewel Detail 1 Chemical Injection Mandrel (with Improved Modified Buttress connections) 2,498 2 HES Sliding Sleeve 7,706 3 BOT SAB-3 Perm. Packer with a K-Anchor and Mill out extension 7,754 4 XN-Nipple (2.75") 7,800 5 3-1/2" Ported Sub 7,808 6 3-1/2" IBTjoint 7,809 7 3-1/2" release (Halliburton Automatic Release Assy.) 7,841 9 Top of Dropped TCP Assy. (28' long) 8,069' Perforation Detail Zone SPF Date Top (FT) Btm (FT) Length (FT) 77-3 5 8/28/2007 7,846.00 7,864.00 18' Last Revised: 9/23/2007 Revised By: CRW ~ . ,~. , Projection System . ~ NAD27 / TM Alaska State Plane, Zone 4(5004), US feet Software System We1lArchitectTM 1.2 North Reference True User Jonethoh Scaie 0.999928 Report Generated 08/13/07 at 14:50:16 °` Wellbore last revised 08/13/07 Database/Source file WA Anchorage/SCU42-OSY.xml '~ 1 alculation method Minimum curvature Nabors 129 (RKB) to Facility Vertical Datum 169.40 feet Horizontal Reference Pt Slot Nabors 129 (RKB) to mean sea level 169.40 feet Vertical Reference Pt Nabors 129 (RKB) Faciliry Vertical Datum to Mud Line (Facility) 0.00 feet MD Reference Pt Nabors 129 (RKB) Section Origin N 0.00, E 0.00 ft Field Vertical Reference mean sea level Section Azimuth 354J1° Chevron ~,~ Actual Wellpath Report BAKER ~ OnTRAK<158- 6600'>NaviTrak<6674-7743'>OnTRAK<7857-8110'> N~16NE~ Page 1 of 6 ~ INTEQ Actual Wellpath Report OnTRAK<158- 6600'>NaviTrak<6674-7743'>OnTRAK<7857-8110'> Page 2 of 6 INTEQ . . Operator .. ~ ~ Chevron Slot SCU42-OSY Area Cook Inlet, Alaska (Kenai Penninsula) Well SCU42-OSY Field Soldotna Creek Unit Wellbore SCU42-OSY Facility Sec.S, T7N, R9W ~LPATH DATA (81 stations) NID Inclination Azimnth TVD Vert Sect North East Grid East Grid Nort6 DLS Toolface Build Rate Turn Rate [feet] [°] [°] [feet] [feet] [feet] [feet] [us survey feet] [us survey feet] [°/100ft] [°] [°/100ft] [°/100ft~ 0.00 0.000 0.000 0.00 0.00 0.00 0.00 34187637 2457937.57 0.00 -99.21 0.00 0.00 158.00 0.320 260.790 158.00 -0.03 -0.07 -0.44 341875.93 2457937.51 0.20 -3.74 0.20 0.00 250.00 0.460 259.650 250.00 -0.08 -0.18 -1.05 341875.32 2457937.41 0.15 66.73 0.15 -1.24 338.00 0.500 268.690 337.99 -0.08 -0.25 -1.78 341874.58 245793734 0.10 -178.96 0.05 10.27 431 00 0 430 268 520 430 99 ; 0 03 0 27 2 54 341873 83 2 9 . . ~ . . - . - . ; - . . 457 3734 0.08 19.99 -0.08 E -0.18 522.00 0.520 272.090 521.99 ~ 0.04 -0.26 -3.29 341873.07 2457937.35 0.10 108.71 O.lO i 3.92 614.00 0.830 344.400 613.98 0.75 039 -3.89 341872.49 2457938.02 0.91 46.91 0.34 78.60 705.00 L210 1.250 704.97 2.35 1.99 -4.05 341872.35 2457939.61 0.53 -146.07 0.42 18.52 797.00 -- - 1.080 --__ 356.470 - 796.95 ------ 4.19 I --___ ____ _~. 3.83 a __.~_ _ -4.08 _---- 34187234 2457941.45 0.18 94.59 -0.14 -5.20 889 00 1A80 5 660 ~ 888 93 5 90 ' , S 55 , 4 05 341872 40 ~~ 24 943 8 j ---- ,- . p . ; . . . ; - . ; . 57 .1 0.19 -58.06 O.OOi 9.99 986.00~ 1150 0.440 985.92 ~_ _ 7.77 ~ _ 7 44 ~ -3.95 T 341872.52 2457945.06 0.13 130.04 0.07 -5.38 1083.00 1.040 8.320 1082.90 9.59 ~ 9.28 -3.81 341872.68 2457946.90 0.19 -42.93 -0.11 8.12 1178.00 1.170 2.650 1177.88 11.39 11.10 ~ -3.64 341872.88 2457948.72 0.18 91.93 0.14 -5.97 1373.00 - --- 1.170~ -- ____ _ 6.510 ____---. -- 1372.84 - _-- - -- 1531 - -- - 15.07 !i -- -3.33 341873.25 2457952.68 __ 0.04 82.72 0.00' 1.98 1467 00 ° 1 200 13 960 1466 82 17 18 16 98 2 98 ' 341873 62 j _ 2 9 9 ~ _ _ -- --_ __T ~' ~~ ~~ r __ ------- . t.; ~ . ~ . . i . . . - . 457 54.5 0.17 135.86 ~ 0.03 ~ 7.93 1564.00 1.180 14.910 1563.80 19.08 ( 18.93 '. ~ -2.48 341874.15 , 2457956.53 ~ 0.03 -100.63 -0.02 0.98 1661.00 1.160 3.120 1660.78 20.99 ~ 20.88' -2.17 341874.48 ~_ _______ __ ~___v _ 2457958.47 _. 0.25 60.89 -0.02 -12.15 1757.00 1.290 12.230 1756.76 22.98 22.90 -1.88 341874.79 2457960.49 0.24 148.63 0.14 9.49 1854.00 1.210 14.570 1853.73 24.98 24.96 -1.40 341875.31 2457962.55 0.10 -7231 -0.08 2.41 1950 00 1 270 450 7 1949 71 26 97 27 00 ~ 1 00 3418 5 73 ~ ~ . . . . . ; . - . 7 . 2457964.58 0.17 38.93 0.06. -7.42 2045.00 1.410 11.910 2044.68 29.12 29.18 -0.63 341876.14 2457966.76 0.18 -160.91 0.15 4.69 2143.00 1.370 11.330 2142.66 31.39 31.51 -0.15 341876.65 2457969.08 0.04 -80.76 -0.04 -0.59 2239.00 1.390 7.180 2238.63 33.63 33.79 0.22 341877.05 245797135 0.11 149.76 0.02 -4.32 2334.00 0.700 66.100 2333.61 34.94 35.17 0.90 341877.74 2457972.72 1.25 127.40 -0.73 62.02 Actual Wellpath Report OnTRAK<158- 6600'>NaviTrak<6674-7743'>OnTRAK<7857-8110'> Page 3 of 6 r~.~ BAKER 1~11~6HES INTEQ . . Operator ,. ~ ~ Chevron Slot SCU42-OSY Area Cook Inlet, Alaska (Kenai Penninsula) Well SCU42-OSY Field Soldotna Creek Unit Wellbore SCU42-OSY Facility Sec.S, T7N, R9W ~LPATH DATA (81 ~ NID [feet] Inclination [°] 2528.00 0.540 2624.00 0.630 2721.00 0.880 2818.00 0.780 2916.00 0.590 2991.00 1.290 3128.00 1390 3223.00 1.350 3320.00 1.310 3419.00 1320 3514.00 1.230 3611.00 0.540 3706.00 0.570 3803.00 3900.00 0.570 ~ 0.590 4094.00 0.410 4287.00 0.190 4480.00 0.360 4577.00 ~ 0.490 46'70.00 2.050 4768.00 2.780 4864.00 5.400 4960.00 6.760 ~ions~ Azimuth TVD Vert Sect North East Grid East Grid North DLS Toolface Build Rate Turn Rate [°] [feet] [feet] [feet] [feet] [us survey feet] [us survey feet] [°/100ft] [°] [°/100ft] [°/100ft] 96.680 2527.60 34.83 35.24 2.83 341879.68 2457972.77 0.02 70.11 -0.02 -0.04 113.080 2623.60 34.49 34.98 3.77 341880.61 2457972.50 0.20 -56.45 0.09 17.08 93.260 2720.59 34.12 34.73 5.00 341881.84 2457972.23 037 -127.04 0.26 -20.43 81.990 2817.58 34.04 34.78 6.40 341883.24 2457972.26 0.20 148.40 -0.10 -11.62 186 540 2915 58 33 58 3437 ' 7 00 341883 84 2457971 84' 1 1 3 9 ' . . ; . ; . . . . 1 1.1 -0.19 106.68 204.030 2990.57 ~ 32.47 33.22 6.62 341883.43 2457970.69 1.00 -73.79 0.93 23.32 193.260 3127.53 29.55 3019 5.61 341882.38 2457967.68 0.20 105.26 0.07 -7.86 201.900 3222.50 27.46 28.03 4.93 341881.67 2457965.53 0.22 -134.19 -0.04 9.09 200.070 3319.48 25.44 25.93 4.12 341880.84 2457963.44 0.06 79.84 -0.04 -1.89 202 260 3418 45 23 41 i 23 81 ~ 330 I 341879 99 I 245796133 ~ 0 05 149 92 ! . . . . . . . 0.01 2.21 204.720 3513.43 21.55 21.87 2.46 341879.12 2457959.41 O.ll 15434 -0.09 2.59 278.540 3610.42 20.76 20.99 1.57 ~ 341878.22 2457958.54 1.23 84.80 -0.71 76.10 292.700 3705.41 21.09 21.24 0.69 341877.35 2457958.80 015 98.44 0.03 14.91 309.580 305 820 3802.41 3899 40 21.66 22 ~ 21.74 2 4 -0.13 0 90 341876.54 341875 77 2457959.31 2457959 92 0.17 0 04 -64.17 1' 0.00 ' 17.40 . . . - . . . . -145.7 ,~ 0.02 -3.88 285.940 4093.39 23.23 23.11 -238 34187430 ~ i 2457960.71 0.13 153.96 -0.09 -10.25 331.240 428639 23.78 23.58 -3.20 341873.49 i 2457961.19 0.16 25.00 -0.11 23.47 343350 4479.39 24.66 24.44 -3.52 341873.17 2457962.06 0.09 -ll.29 0.09 6.27 340.330 4576.39 25.37 25.13 -3.75 341872.96 2457962.74 0.14 -0.66 0.13 -3.11 339 830 4669 36 27 3b 27 06 4 46 341872 28 24 964 9 . . . ~ . - . . 57 .6 1.68 39.72 1.68 -0.54 351.440 4767.27 31.42 31.06 -5.42 341871.37 2457968.70 0.89 15.06 0.74 11.85 358.820 4863.02 38.26 37.88 -5.86 341871.02 2457975.52 2.78 7.02 2.73 7.69 0240 4958.48 48.39 48.04 -5.93 341871.09 2457985.69 1.43 -12.69 1.42 1.48 357.900 5055.64 61.16 60.85 -6.16 341871.03 2457998.49 1.56 -14.78 1.53 -2.39 . Actual Wellpath Report OnTRAK<158- 6600'>NaviTrak<6674-7743'>OnTRAK<7857-8110'> Page 4 of 6 rr..~ BAKER Nu6NEs INTEQ . , perator _ _...___ _ _ ___.___..._ _ _ _ _ _ _ _ __._. . , , . ~ :~ _ _. ~ __ -_ a Chevron Slot SCU42-OSY Y.~._. _._________.... _ ._ _ . . ._ __ Area ___ . ___ ._. _-------- Cook Inlet, Alaska (Kenai Penninsula) Well SCU42-OSY Field Soldotna Creek Unit Wellbore SCU42-OSY Facility Sec.S, T7N, R9W LLPATH DATA (81 stations) MD Inclination Azimuth TVD Vert Sect North East Grid East Grid North DLS Toolface Build Rate Turn Rate [feet] [°] [°] [feet] [feet~ [feet] [feet] [us survey feet] [us survey feet] [°/100ft] [°] [°/100ft] [°/100ft] 5251.00 11.390 357.780 5245.93 93.18 92.85 -7.82 341869.80 2458030.51 2.20 9.53 2.18 1.68 5348.00 13.110 359.050 5340.72 113.71 113.42 -8.38 341869.52 2458051.09 1.79 11.62 1.77 1.31 5437.00 14.420 0.130 5427.16 134.81 134.60 -8.52 341869.66 2458072.26 1.50 -7.68 1.47 1.21 5540.00 15.750 359.470 5526.61 161.51 161.40 -8.62 341869.92 2458099.06 1.30 -44.07 1.29 -0.64 5635 00 17 150 53 5 030 5617 72 18837 ; 188 25 ; 9 95 3 868 9 . . , . ; . - . 41 . 5 2458125.92 1.98 -11.96 1.47 -4.67 5732.00 18.120 354370 5710.16 217.75 217.51 -12.67 341866.63 2458155.22 1.02 143.73 1.00 -0.68 5829.00 17.410 ~ 356.130 5802.54 247.34 247.00 -15.13 341864.56 2458184.73 0.92 25.13 -0.73 1.81 5927.00 17.930 356.920 5895.92 277.07 276.69 -16.93 34186316 2458214.45 0.58 -76.10 0.53 0.81 6025.00 18.080 355.080 5989 12 307.36 , 30691 ~ -19.04 341861 46 2458244.68 0.60 -132.19 0.15 -1.88 118.00 7.900; 54.430 07?.57 36.08 _ - 35.51 ' --~ 21.67 , _~ T 341859.22 ; ~ - -_. _.. 2458273.32 ! .29 ~ -149J1 _ .r__.__ -0.19 ------ -OJO 6215.00 17.530f ~ 6169.97 ~ 365.59 364.87 -24.72 ~ 341856.56 ~ 2458302.71 ~ 0.44 175.92 -0.38 -0.74 6312.00 16.800 ~353.890 6262.65 394.21 39333 -27.81 341853.85 ~ _......__- ~ 2458331.21 - -- 0.75 -133.05 -0.75 0.19 6409.00 16.460 352.590 6355.59 421.96 420.89 -31.07 341850.96 2458358.81 0.52 -157.74 -0.35 -1.34 6504.00 15.090 350.420 6447.01 ; 447.75 ', 446.43 { -34.87 341847.51 2458384.40 1.57 167.63 -1.44 -2.28 6600 00 ; 13 460' 351 960 6540 05 ! 471 37 469 82 ; 38 51 34 8 8 i . . . . . . - . 1 44.1 2458407.83 1.74 140.88 -1.70 1.60 6674.00 12.390 ~ 356.140 6612.17 487.91 486.27 -40.25 341842.67 245842430 1.92 174.65 -1.45 5.65 6771.00 11.040~ 356.800 6707.15 507.59 505.93 -41.47 341841.71 2458443.97 1.40 -17136 -1.39 0.68 6867.00 8.470 ~ 354.140 6801.75 523.85 522.14 -42.70 341840.69 2458460.20 2.72 -179.14 -2.68 -2.77 6963.00 _._.____ 7.290 ______________ . 354.000 _ ._____- 6896.85 _ ._ . _ 537.01 __~ 535.23 -44.06 341839.51 2458473.30 1.23 -174.96 -1.23 -0.15 7059 00 , 6 450' - 353340 -- _ _ _~.. ,_ 6992 16 _ - --_. 548 49 ._ _______ 546 64 ~ ___ __ 4 32 _ _.____ __ _.-- i 34 8 . ___ __-____.- - - _ _.______ 7k _... ~~' ' --__..~_ . . , r . - 5 183 .40 2458484.73 0.88 ~ 160.8 , ~ -0.87 -0.69 7157.00 S.OSOj 358.960 7089.66 558.30 i ----- 556.42 -46.04 ~ 341837.82 2458494.52 1.54 -165.88 -1.43 5.73 7252.00 3.440 352.090 7184.40 56532 Y 563.43 i -46.51 341837.44 2458501.53 1.77 17238 -1.69 -7.23 7349.00 1.690 0.130 728130 569.65 567.74 -46.91 341837.10 2458505.85 1.84 109.16 -1.80 8.29 7445.00 1.600I, 23.190 7377.26 ! 572.23 ~ 570.39 ! -4638 ~ 341837.67 ' 2458508.49 0.69 4.97 -0.09' : 24.02 _ _. 7539.00 _ --- 1.660 ____ - -- 23.370 -- ---- '7471.22 _ _. _.. 574.58 _ _ - - -- 572.84 45.32 41838.76 __._ 2458510.93 ` __.-_~. 0.06 ` _ ___ 139.80 ! _____ _ -- 0.06 - --_..--- 0.19 Chevron Actual Wellpath Report ~ OnTRAK<158- 6600'>NaviTrak<6674-7743'>OnTRAK<7857-8110'> ~ Page 5 of 6 sA ~~•~ 1~1 61R~1 ES INTEQ . . Operator ,. ~ ~ Chevron Slot SCU42-OSY Area Cook Inlet, Alaska (Kenai Penninsula) Well SCU42-OSY Field Soldotna Creek Unit Wellbore SCU42-05Y Facility Sec.S, T7N, R9W / ELLPATH DATA (81 stations) NID [feet] Inclination [°] Azimuth [°] TVD [feet] Vert Sect [feet] North [feet] East [feet] Grid East [us survey feet] Grid North [us survey feet] DLS [°/100ft] Toolface [°] Build Rate [°/100ft] Turn Rate [°/100ft] 7644.00 1.560 26.550 7576.18 577.13 575.52 -44.08 341840.04 2458513.59 0.13 8.92 -0.10 3.03 7743.00 2.070 28.760 7675.13 579.76 578.29 -42.61 341841.54 2458516.34 0.52 66.04 0.52 2.23 7857.00 2.120 31.640 ~ 7789.05 583.15 581.89 -40.52 341843.68 2458519.91 0.10 1.49 0.04 2.53 7976.00 2.240 31.720 7907.97 - 586.77 585.74 -38.14 341846.11 2458523.73 0.10 -81.17 0.10 0.07 8050.00 2.280 26.670~ 7981.91 ; 589.17 ~ 588.29 -36.72 341847.57 2458526.26 i 0.27 0.00 0.05; -6.82 8110.00 2.280 26.670 8041.86 : 591.19 ; 590.42 -35.65 341848.67 2458528.38 0.00 0.00 0.00 HOLE & CASING SECTIONS Ref Wellbore: SCU42-OSY Ref Wellpath: OnTRAK<158- 6600'>NaviTrak<6674-7743'>OnTRAK<7857-8110'> String/Diameter Start MD [feet] End MD [feet] Interval [feet] Start TVD [feet] End TVD [feet] Start N/S [feet] Start E/W [feet] End N/S [feet] End E/W [feet] 9.625in Casing Surface 0.00 3052.00 3052.00 0.00 3051.55 0.00 0.00 31.92 6.11 . TARGETS ame MD [feet] TVD [feet] North [feet] East [feet] Grid East [us survey feet] Grid North [us survey feet] Latitude [°] Longitude [°] Shape P t ti f ll 3 16 M 07 7785.40 585.80 -54.25 341830.00 2458524.00 60 43 35.285N 150 53 00.585W polygon ene ra on or we - ar- / ELLPATH C OMPO5ITION Ref Wellbore: SCU42-05Y Ref Wetlpathc OnTRAK<158- 6600'>NaviTrak<6674-7743'>OnTRAK<785 7-8110'> Start MD [feet] End MD [feet] Positional Uncertainty Model Log Name/Comment Wellbore 0.00 2991.00 OnTrak (Standard) OnTRAK MWD <158 - 2991'> SCU42-OSY 2991.00 5829.00 OnTrak (Standard) OnTRAK MWD <3128 - 5829'> SCU42-OSY 5829.00 6312.00 OnTrak (Standard) OnTRAK MWD <5927 - 6312'> SCU42-OSY 6312.00 6504.00 OnTrak (Standard) OnTRAK MWD <6409 - 6504'> SCU42-OSY 6504.00 6600.00 OnTrak (Standard) OnTrak MWD <6600'> SCU42-OSY 6600.00 7743.00 Na~iTrak (Standard) NaviTrak MWD<6674 - 7743'> SCU42-OSY 7743.00 8110.00 OnTrak (Standard) OnTrak MWD<7857 - 8110'> SCU42-OSY SURVEY LOG COMMENTS MD [feet] Inclination [°] Azimuth [°] TVD [feet] Log Comments 8110.00 2.280 26.670 8041.86 Projected Data - NO SURVEY ~ ~ Chevron ~~'r Actual Wellpath Report BAKER ~ OnTRAK<158- 6600'>NaviTrak<6674-7743'>OnTRAK<7857-8110'> Nu6N~~ ~ Page 6 of 6 INTEQ MEMORANDUM ~ TO: Jim Regg i~~ ~~~Z,~~~ 7 P.I. Supervisor FROVt: Lou Grimaldi Petroleum Inspector State of Alaska ~ Alaska Oil and Gas Conservation Commission DATE: Monday, .August 20, 2007 SUBJECT: Mechanical IntegriryTests UNION OIL CO OF CALIFORNIA 42-OSY SOLDOT~IA CK UNIT 42-05Y Src: Inspector ~vn~r_rnNFTnFNTIAL Reviewed By: /, n P.I. Suprv ~ Comm Well Name: SOLD07'NA CK LJNIT 42-OSY ApI Well Number: 50-133-20570-00-00 Inspector Name: Lou Grimaldi mitLG070820070403 Insp Num: Permit Number: zo7-o82-o Inspection Date: $%18~200~ Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 4z-o'Y ;Type Inj. ^~ TVD ~~oo , IA ! a sooo sooo ; sooo ~ ! P.T. ; zo~oazo jTypeTest ~, srr ' Test psi , sooo ,`' OA ' o , o ~~ o ~ ~ ~ ~ Interval oT~R p~ P %~ Tubin o o g` i ~ o ~ o ~ ' Pre-injection MIT. Packer depth is MD, not TVD. Prior to MIT, *N* test tool set at 7784 and t N tubing tested to 3~00 psi for 15 minutes after l l CS O ~ setting packer "OK". Tubing and OA ope n during MIT. OA on vacuum, explained to me that ar e annu OA,~Ir1 lap left uncemented for possib injection. Monday, August 20, 2007 Page 1 of l , , Regg, James B (DOA) ~ r~ L Page 1 of 1 From: Greenstein, Larry P [Greensteinlp@chevron.com] Sent: Thursday, September 06, 2007 4:25 PM To: Regg, James B (DOA) Cc: Merle, Greg L; Walsh, Chantal [Petrotechnical] ~/7/~~ Subject: RE: MIT for SCU 42-05Y (P7D # 2070820) ,~ ~~ Attachments: SCU4205Y_TBG_Test.pdf; SCU4205Y_MIT.pdf F~ere's what I've received Jim. There are two charts. One sho~vs the tubing pressure test to 5000# on the 17th (unwitnessed) and the ather shows the an~ulus pressure test to 5000# an the 18th (witnessed by Lou). Neither of these show th~e o~her pressures at the time of the test. 1'm sure Lou wrofie th~m down on the witnessed portion; but I can't find anyone that wrote them down for us...sorry. if I could ge~ a copy of the pressures that Lou documented, I wc~uld like to add it to our 5Y we31 files. As we discussed, the weil is currently not planned to have injection until December at feast. We vsaill be holding off an fihe follow-up M!T until the injection begins and has stabilized. Thanks Jim. Larry From: Greenstein, Larry P Sent: Thursday, August 30, 2007 7:43 AM To: 'Regg, James B (DOA)' Subject: RE: SCU 42-05Y You got it Jim. I just got a capy of the chart and I`II get the form in to you guys soan. We still plan on calling you in for a follow-up IViIT after injection begins and gats stabilized. Larry From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, August 29, 2007 11:35 AM To: Greenstein, Larry P Cc: Fleckenstein, Robert J (DOA) Subject: SCU 42-05Y Larry - When you get a chance we need a MIT report for the test done 8/18/2007 witnessed by Lou Grimaldi. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 9/7/2007 RE: Commencement of Injecti: perations - Swanson River Field Tyonek 77-3 Sand St... Page 1 of 3 ~ Maunder, Thomas E (DOA) From: Ayer, Phil M [pmayer@chevron.com] Sent: Wednesday, August 29, 2007 12:19 PM To: Maunder, Thomas E (D~A) Cc: Greenstein, Larry P Str~ ~ ~~~ ~ ~~~ ~ Subject: RE: Commencement of Injection Operations - Swanson River Field Tyonek 77-3 Sand Storage (Storage injection Order #6) Tom, As per your request, SCU 42-05Y was perforated yesterday and is in its post-perf production clean up phase. Phil Phil Ayer MidContinent/Alaska Business Unit Chevron North American Exploration and Production Company 909 West 9th Avenue, Anchorage, AK 99501 907-263-7620 (work) 907-250-2711 (cell) 907-263-7847 (fax) From: A r, Phil M Sent: Tues August 14, 2007 7:58 AM To: `Maunder, Th s E (DOA)' Cc: Greenstein, Larry , egg, James B(DOA) Subject: RE: Commencem of Injection Operations - Swanson River Field Tyonek 77-3 Sand Storage (Storage Injection Order #6) I suspect that the rig will move off in a wee d that we would perforate no sooner then another week from then. Hence my 8/27/07 date as the e_a_ rliest that injec would commence. It could be up to two to three weeks later. My purpose in sending the original email was to prov ou the required 10 day minimum notification. All paperwork will be submitted with ample time for you to pr ~ e review. We are not in a rush. Phil Phil Ayer MidContinent/Alaska Business Unit Chevron North American Exploration and Production Company 909 West 9th Avenue, Anchorage, AK 99501 907-263-762Q (work) 907-250-2711 (ceN) 9/23/2008 Page 1 of 1 ~ ~ Maunder, Thomas E (DOA) ~~`~ ~-O ~-.~ From: Maunder, Thomas E (DOA) Sent: Monday, August 27, 2007 9:29 AM To: Maunder, Thomas E(DOA); 'Walsh, Chantal jPetrotechnical]'; 'Jill Simek' Cc: 'Buster, Larry W Subject: RE: Thursday August 23 10 AM Chantal and Jili, Just to close the loop. Thanks for meeting with me last week and bringing the copy of the USIT. The log does indicate that isolation was achieved as designed. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Wednesday, August 22, 2007 11:03 AM To: 'Walsh, Chantal [Petrotechnical]'; Jill Simek Cc: Buster, Larry W Subject: RE: Thursday August 23 20 AM Thanks Chantal. this works for me. Tom From: Walsh, Chantal [Petrotechnical] [mailto:WalshC@chevron.com] Sent: Wednesday, August 22, 2007 iQ:30 AM To: Maunder, Thomas E(DOA); Jill Simek Cc: Buster, Larry W Subject: Thursday August 23 10 AM Tom and Ji(I, Please plan to meet at Tom's office at the AOGCC tomorrow morning at 10 AM to review the SCU 42-05Y USIT log and morning report summaries for the 7" production casing. Chantat 8/27/2007 ~ ~ Page 1 of 1 Maunder, Thomas E {D4A) ,~ ~ ~ _. ~ aC~ From: Maunder, Thomas E {DOA) Sent: Friday, August 17, 2007 8:29 AM To: 'Brandenburg, Tim C' Cc: Regg, James B(DOA); Walsh, Chantal [Petrotechnical]; Buster, Larry W Subject: RE; Chevron Weekly Activity Thank you. I look forward to receiving the information. 7om From: Brandenburg, Tim C [mailto:brandenburgt~achevron.com] Se~rt: Friday, August 17, 2007 8:28 AM To: Maunder, Thomas E (DOA) Cc: Regg, ]ames B(DOA); Walsh, Chantal [Petrotechnical]; Buster, Larry W Subject: RE: Chevron Weekly Activity Tom, The USIT log indicated a very good cement job at and above the 77-3. Chantal is still the engineer and I will have her provide the information as requested. Tim From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, August 17, 2007 8:17 AM To: Brandenburg, Tim C Cc: Jim Regg Subject: RE: Chevron Weekly Activity Tim, Thanks for the update. 1 would like some further information on the 7" cementing job on 42-05Y. Is Chantel still the engineer to speak with? At a minimum I'd like to see the operations reports for the trip prior to running casing, running and cementing the casing and the cement evaluation log. Thanks in advance, Tom Maunder, PE AOGCC From: Brandenburg, Tim C [mailto:brandenburgt@chevron.com] Sent: Friday, August 17, 2007 8:09 AM To: Maunder, Thomas E (DOA) Subject: Chevron Weekly Activity 8/27/2007 ~ • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO• '~~`~ ~~~~~U~~ DATE: Monday, August 20, 2007 • Jim Regg P.I. Supervisor SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 42-OSY FROivt: Lou Grimaldi SOLDOTNA CK UNIT 42-OSY Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~. Comm Well Name: SoLDOTT1A CK t1tvI7' 42-osY API Well Number• so-t33-2o570-00-0o Inspector Name• Lou Grimaidi Insp Num: mitLG070820070403 Permit Number: 2o7-os2-o Inspection Date: 8itsi2oo~ Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ a2-osY ,TYPe Inj. '' ~ ~ TVD ~ ~~oo ! IA o I sooo sooo- s o p T i zo~oazo ~TypeTest I sPT ' Test psi ~~ sooo I OA ~ o ~ o i --+ o ~ o ~ -- Interval oT~R p/F P /' Tubing ~ o o ~ o ~ o , NOtCS' Pre-injection MTI'. Packer depth is MD, not TVD. Prior to MIT, "N* test tool set at 7784 and ~ tubing tested to 3500 psi for 15 minutes after setting packer "OK". Tubing and OA open d uring MIT. OA on vacuum, explained to me that OA/IA lap left uncemented for possible annular injection. Monday, August 2Q 2007 Page i of 1 RE: Commencement of Injection Operations - Swanson River Field Ty~ k'77-3 Sand St... Page 1 of 2 ~ Maunder, Thomas E (DOA) From: Ayer, Phil M[pmayer@chevron.com] ~ ~~_:~ ~-'~ ~--~ Sent: Tuesday, August 14, 2007 7:58 AM To: Maunder, Thomas E (DOA) ~~ ~ ~ Cc: Greenstein, Larry P; Regg, James B(DOA) Subject: RE: Commencement of lnjection Operations - Swanson River Field Tyonek 77-3 Sand Storage (Storage Injection Order #6) I suspect that the rig will move off in a week and that we would perforate no sooner then another week from then. Hence my 8/27/07 date as the earliest that injection would commence. It could be up to two to three weeks later. My purpose in sending the ariginal email was to provide you the required 10 day minimum notification. All paperwork will be submitted with ample time for you to provide review. We are not in a rush. Phil Phit Ayer MidContinentJAlaska Business Unit Chevron North American Exploration and Production Company 909 West 9th Avenue, Anchorage, AK 99501 907-263-7620 (work) 907-250-2711 (cell) 907-263-7847 (fax) From: Maunder, Thamas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, August 14, 2007 7:45 AM To: Ayer, Phil M Cc: Greenstein, Larry P; Regg, )ames B(DOA) Sabject: RE: Commencement of Injection Operations - Swanson River Field Tyonek 77-3 Sand Storage (Storage Injection Order #6) Have the rig operations been completed? Submitting the completion report and other information as soon as possible will allow me to do my review before storage injection is initiated. Thanks in advance. Tom Maunder, PE AOGCC From: Ayer, Phil M [mailto:pmayer@chevron.com] Sent: Tuesday, August 14, 2007 7:18 AM To: Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Regg, James B(DOA) Subject: RE: Commencement of Injection Operations - Swanson River Field Tyonek 77-3 Sand Starage (Storage Injection ~rder #6) No it has not but all you mention will be done before we start any injection. 8/14/2007 RE: Commencement of Inject~. Operations - Swanson River Field Ty~k 77-3 Sand St... Page 2 of 2 Phil Ayer MidContinent/Alaska Business Unit Chevron North American Exp{oration and Productian Company 909 West 9th Avenue, Anchorage, AK 99501 907-263-7620 (work) 907-250-2711 (celi) 907-263-7847 (fax} From: Maunder, Thomas E (DOA) [m8ilto:tom.maunder@alaska.govJ Sent: Monday, August 13, 2007 9:54 PM To: Ayer, Phit M Cc: Whitacre, Dave S; Greenstein, l.arry P; Regg, Jame.s B(DOA} Subject: RE: Commencement of Injection Operatians - Swanson Rrver Fiefd Tyonek 77-3 Sand Starage (Storage InjECtian Order #6) Phil, Has the 407 completion report been filed yet? I atn answering this from my home so I don't have aecess to the log of items received. Submitted documentation should inciude the daily report in€ormation inctuding cementing information, bond log and prelirninary MIT af the tubing x casing annuius. I look forward to yaur reply. Likety we will speak tomorrow. Tom Maunder, PE AOGCC -----Origirial Message----- From: Ayer, Phil M [mailto:pm,ayer@chevron.com] Sent: Man 8/13/2007 5:56 PM To: Maunder, Thomas E (DOA) Ce: Whitacre, Dave S; Greenstein, Larry P Subject: RE: Commencement of Injection Operations - Swanson River Field Tyonek 77-3 Sand Storage (3torage Injection Order #6) Tom, Chevron intends to commence gas injection inta the SCU 42-OSY well as early as Monday, August 27, 2007, depending on completion of the post perforation clean up production period. T'he date that adequate well clean up occurs cannot be predicted precisely. > Phil Ayer > > MidContinent/Alaska Business Unit > Chevron North American Exploration and Production Company > 909 West 9th Avenue, Anchorage, AK 99501 > > 907-263-7620 (work) > > 907-254-2711 (cell) > 907-263-7847 (f~) > 8/14/2007 • Page i of 1 ~ Maunder, Thomas E (DOA) From: Walsh, Chantal [Petrotechnical] {WalshC@chevron.com] Sent: Friday, August 03, 2007 1028 AM To: Regg, James B(DOA); aogcc_prudhoe bay@admin.state.ak.us; Fleckenstein, Rober# J (DOA) Cc: Maunder, Thomas E(DOA}; Maunder, Thomas E(DOA) Subject: RE: SCU 42-05Y BOPE Test Report Attachments: BOP Test for Nabors 129 7-24-07 {2).xls I believe this report was not attached in the earlier transmission. Thank you for your patience. Chantal Waish 263-7627 From: Walsh, Chantal -Petrotechnical [contractor] Sent: Tuesday, July 31, 2007 1:59 PM To: yim_regg@admin.state.ak.us'; 'aagcc prudhoe_bay@admin.state,ak.us'; 'bob_fleckenstein@admin.state.ak.us' Cc: 'Maunder, Thomas E(DOA)'; 'Thomas Maunder'; Harness, Evan Subject; SCU 42-05Y BOPE Test Report Gentlemen, Please find attached the BOPE report dated Juiy 24, 2007 for the Swanson River well, SCU 42Q5Y. We recognize our failure to provide this documentation in a timely manner. Please let me know if you require further information. Chantal Walsh 907-263-7627 (o~ce) 8/27/2007 • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Su~nit ta: Contractor: Nabors ^ Rig No_: 129 DATE: 7/24i2007 Rig Rep.: Hansan/Applegate Rig Phone: 283-2539 Rig Fax: Operatar. Chevronlfexaco Op. Phone: 283-2535 t)p. Faac: 283-2550 Rep._ DunnBradford Field/Unit 8~ Well No.: SCU 42-05Y PTD # 207-082 Opera6on: Drig: X Waricover_ Test: Infiat: X Weekty: Test Pressure: Rams: 250/5400 Annufar: 250l3504 TEST DATA MISC. INSPECTIONS: Test Resutt Test Result Locafion Gen.: P Weli Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec_ P Standing Order Posted p BOP STACK: Quantity Size Test Result Annular Preventer 1 i'1 P Pipe Rams 1 2 7/8x5 P Lower Pipe Rams 1 4 P Blind Rams 1 11 P Choke Ln. Valves 1 3 U'!6 P HCR Valves 1 31/16 FP Kill Line Valves 2 31/16 P Check Vahre 1 31h6 P MUD SYSTEM: V'~sual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow lndicator P P Meth Gas Detector P P H2S Gas Detector P P Test Resufks Expior.: Bi-Weekly Valves: Lower Kelly 1 P Bail Type 1 P lnside BOP 1 P FL~QR SAFETY VALVES: Quanfity Test Resu Upper KeBy 1 P CHOKE MANIFOLD: Quantity Test R No. Valves 12 P Manual Chokes 1 P Hydraulic Ghokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 3100 P Pressure After Closure 1900 P 200 psi Attained 28 sec. P Fult Pressure A#tained 2 min P Bfind Sw~ch Covers: All stations P Nitgn. Bottles {avg): 3~ 2Q00 psi Number of Failures: 7 Test Tme: 8 Hours Components tested 25 Repair or replacement of ~uipment will be made within (dan~) days. Notify the North Slope Inspector 659-3607, follow rnrith writEen confimtafion to Superv~ser at: ; Remarks: Super choke position indicator in do4house needs reaairedl reafaced 24 HOUR NOT{CE G{VEN YES X NO Waived ~y Date Time Witness Lou Grimaldi Test start 21:~ Fnish 5:00 BOP Test {for rigs) BFL Q4/28/05 SOP Test for Nabors 129 7-24-07 (2).xls • ~ STATE OF ALASKA ALASKA DIL AND GAS CONSERVATION COMMI5SIE~N 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF Union Oil Company of California, a wholly-owned indirect subsidiary o~ Chevron Corporation, for an arder granting an exception to the spacing requirem~nts of 20 AAC 25.055(a)(2) and 20 AAC 25.OSS(a)(4} to provide for the drilling, completion, gas storage and regular production of the Swanson River Unit 42-OSY well within 1 S00 feet of a property line and within 3Q00 feet of a well capable of producing from the same pool within the Swansan River Field, Soldotna Creek Unit. ) Canservatiaza 4rder 585 ) ) } Swansan River Unit 42-OSY ) Gas WeII ~ ~0~1 ~C~ ~`a- } } August 1, 2t}47 ) IT APPEARING THAT: l. Union Oil Company of California ("Union Oil"}, a wholly-owned indireet subsidiary af Chevron Carporation, by a letter dated May 14, 2407 and received by the Alaska. C?il and Gas Conservation Commission ("Commission"} on May 24, 20U7, has requested an order allowing an exception ta the spacing requirements of 20 AAC 25.055(a)(2} and 20 AAC 25.055(a)(4} to provide for the drilling, completion, gas storage and regular production of the Swanson River Unit ("SRU") 42-OSY well within 1500 feet of a property line and within 3QOU feet of a w~ll capable of producing from the same paol within the Swanson River Field, Soidot,na Creek Unit. 2. On June l, 2U07, a pubiic hearing was scheduled for July 12, 2007. The hearing was subseguently rescheduled to July 30, 2007, and on June 27, 20Q7, pursu~r-t to 20 AAC 25.544, the Cannmission published a notice of opportunity for public hearing in the Ancharage Daily News. 3. No written requests for a hearing were received by July 12, 2007, and no written pratests or camments to the application were received by July 27, 2007. 4. The public hearing was vacated on July 17, 2Q07. • • FINDINGS: 1. Union Oil is the operator af the Swansan River Field, Soldatna Creek Unit. 2. The SRU 42-OSY well is proposed as a deviated gas storage and prvduction wetl with a surface location 49~ feet frorn the east tine (FEL) artd 2712 feet fram the north tine (FNL) of Section 5, T7N, R9W, Seward Meridian ("S.M."), and a projected bc>ttom hole location 489 feet FEL and 2327 feet FNL of Section 5, T'yN, R9W, S.M. 3, The SRU 42-QSY well will target gas reservoirs thaf caFt be discontinuous in the Tyonek Formation. 4. Gas storage injection in the Tyanek 77-3 sand is authorized by Storage Injection 4rder Na. b. 5. Union OiI sent natice of the application €or exception to the well spacing rec~uirements of 20 AAC 25.OS5(a)(2) and 20 AAC 25.055(a}{4) by certified maul to all owners, landawners, and operators of aii properties within 3000 feet of the anticipated productive interval of the proposed SRU 42~OSY well. 6. The SRU 42-d5Y well wiil be withir~ 1540 feet of a property tine where the owner and landowner are the same, but the landawners hold different royalty percentages in the offsetting leases, 7. The SRU 42-OSY well will be within 30f}0 of a well capable of producing from the same pool. CONCLUSIONS: 1. An except~on to the well spacing requirernents of 20 AAC 25.055(a)(2) and 20 AAC 25.055(a~4} is necessary to allow far drilling, completioM, gas storage and regular production of the SRU 42-d5Y well in the Tyonek Formation, Swanson River Unit, Kenai PeninsuIa Barough, Alaska. 2. Granting a spacing exception to allow drilling, completian, gas storage and regui~r productian of the SRU 42-USY well wili not result in waste or jeopardize the carrelative rights af adjoining or nearby owners, operators, and landowners. Canservation Order No. S85 Effective August 1, 200'7 Page 2 af 3 • ~ NOW, THEREFORE, IT iS ORDER.~D: Pursuant to the Commission's authority under AS 31.OS.Q34 and AS 31.05.100, the Camrnission hereby approves Union Oil's application for exception to the weil spacing provisions of 20 AAC 25.055(a)(2) and 20 AAC 25.055(a)t4) for the purpose of drilling, completian, gas storage, and regular praduction of the SRU 42-OSY well. Union Oil rnay proceed with drilling, completion, gas storage and regular praduction as long as it cvmplies with the Undergxound Gas Storage Agreement, Swanson River Gas Starage Facility Agreement #3, Agreement No. AA-085943 between the United States af America (through its Bureau af Land Management} and Union Oil, and all appli~able ~aws. /"` DONE at Anchorage, Alaska and datec~,~Cti"gy'~ 1, ~~ ~~ . _~'~ ~ ~ ~ < r_~`- . ;~'-. .:::,' ~ - ~; n, Chairman Gas Conservation Commission Daniel T. Sea~unt, Jr., Commissioner Alaska Oil and Gas Conservation Commissian AS 31.05.0$0 provides that within 2U days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an applic.ation for rehearing_ A request far rehearing must be received by 4:30 PM on the 23`~ day following the date of the order, ar next working day if a holiday or weekend, to be timely filed. The Cnmmission shalt grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes} an order upon rehearing, both being the finat order of the Commissian, to appeal the decision to Superior Caurt. Wherc a request for rehearing is denied by nonactian af the Commission, the 30.day period for appeai ta Superior Court runs from the date on which the reyuest is deemed denied (i.e., 10`" day after the application for rehearing was filed). Gonservation ~rderNo. 585 ~ffective August l., 2UU? Page 3 of 3 • Fage 1 af 1 ~ Maunder, Thomas E (DOA) From: Walsh, Chantal -Petrotechnical [contractorJ [WalshC@chevron.com] Sent: Tuesday, July 31, 2007 1:48 PM To: Regg, James B{DOA); aogcc prudhoe_bay@admin.s#ate.ak.us; Fie~kenstein, Robert J (DOA) Cc: Maunder, Thomas E(DOA); Maunder, 'Thomas E(DOA); Harness, Ev~n Subject: SCU 42-05Y Diverter Systems Report Attachments: 7-17-07 Nabors 129 Diverker Test.xls Gentlemen, Please find attached the initial diverter systems inspection report dated July 17, 2007 €or the Swanson River well, SCU 4205Y. We recognize our failure to provide this dacumentation in a t+mely manner. Ptease let me know if you require further information. Chan#al Walsh 907-263-7627 (office) 8/27/2007 ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATiON COMMISSION Diverter Systems lnspection Report su~cnit b~: DATE JULY 17-07 Operation: DevelopmeM X E~loratory: Drlg Corrtractar. Nabors Alaska Drtlling Rig No_ 129 PTD # 204-082 Rig Ph. # 283-2535 Operator: Union Oil of CaNforrua Oper_ Rep__ Bradf~dlD~ FieldlUnit & Well No.: SCU 42-05Y Rig Rep.: RadgerstCompton Location: Sec. 5 T. 7N R. 9VN,SM Mer~ ISC. WSPECTIONS: Location Gen.: G WeN Si~: X Housekeeping: G {Gen.) Drlg. Rig: G Reserve Pit: G Flare Pit WA DIVERTER SYSTEM INSPECTION: I Diverter Size: 13-5l8 ~. ,Divert Valve(s) Full Opening: 1 Valve(s) Auto & Simuttaneaus: yes 'Vent Line(s) Size: 12 in. Ver~t Line(s) Length: 120 R Line(s) Bifurcated: NO Line(s) Down Wind: yes Line(s) Anchored: yes 'Tums Targeted / Long Radius: WA Non Compliance Items Q Remarks: ACCUII~UiATOR SY3TEM: Systems Presstae: 3000 psig Press~ue After Closure: 2300 psig 2~ ps+ Attamed After Closure: 0 min 28 sec. 5ystems Pres~t~e Attained: 1 mim 25 sec. Nitrogen Bnttles_ 2100 psig MUD SYSTEM MISPECTfON: Light Alarm 7rip T~tk: X X Mud P'rts: X X ~r Monitor. X X GA3 DETECTOR3: Light Alarm Meth~e X X Fly~ogen S~ide: X X AOGCC REP.: ChUCk Ch6aV6 OPERATOR REP.: ./aSOA B/"ddf+Dlid Diverter Test 95 Ver(for rigs) BFL 05129/03 7-17-07_Nabors 129 Diverter Test.xls ~ ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, July 11, 2007 8:10 AM °~'~~ ~~v~ To: 'Walsh, Chantal -Petrotechnical [contractor]' Subject: RE: 42-05Y Chantal, Sorry I missed that. Allowing a 12" line while drilling 12-1/4" hole has been a practice that has been approved previously. 12-1/4" hole has an area ~4% larger than the 12" ID. A copy of this message should be available at the rig. Tom Maunder, PE AOGCC From: Walsh, Chantai -Petrotechnical [contractor] [mailto:WalshC@chevron.com] Sent: Wednesday, July 11, 2007 8:04 AM To: Maunder, Thomas E (DOA) Subject: RE: 42-05Y Tom, In our permit to drill application for the SCU 42-05Y well, we requested a variance from 20 AAC 25.035 to utilize a diverter vent line with a diameter of 12" to account for the smaller hole size, 12-1/4", we are planning to drill out of the conductor. Can you please address this? Thank you, Chantal Walsh 263-7627 Prom: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, ]uly 09, 2007 10:22 AM To: Walsh, Chantal -Petrotechnical [contractor] Cc: Greenstein, Larry P Subject: RE: 42-05Y Chantal, This message and our conversation answers my questions. When storage injection actually starts, a witnessed MIT is required. Larry is familiar with the protocols. Tom Maunder, PE AOGCC From: Walsh, Chantal -Petrotechnical [contractor] [mailto:WalshC@chevron.com] Sent: Monday, ]uly 09, 2007 10:06 AM To: Maunder, Thomas E (DOA) Subject: RE: 42-05Y Tom, We intend to pressure test the annulus (MIT) prior to shooting the guns. Please let me know if you need additional information. 7/11/2007 ~ • Page 2 of 2 Thank you, Chantal From: Maunder, Thomas E (DOA) [maiito:tom.maunder@alaska.govj Sent: Friday, July 06, 2007 3:30 PM To: Waish, Chantat -Petrotechnical [cantractor] Subject: 42-05Y Chantai, Just to close the loop on our discussion. 1. Rig is Nabors 129, no issue here. 2. It is planned to test the casing to 5000 psi when you bump the plug. The Chevron cementing expert wilt be at the location and specialized equipment has been aMered. 3. Although accomplishing step 2 will test the casing, 1 don't find that there will be a test of the tubing x casing annulus prior to shooting the guns. Maybe the procedure does not go to that detail. I wauld presume th~t some sort of pressure test will be accomplished when the packer is set and when the sleeve is closed after underbalancing. Look forvvard to speaking with you on Monday. Tom Maunder, PE AOGCC 7/11/2007 ~ ~ ~ ~ ~! ~ ~ ~ SARAH PALIN, GOVERNOR ~5~ O~j ~~S 333 W. 7thAVENUE, SUITE 100 COI~TSERQA~`IO1~T CO1rIlrIISSIO1dT ANCHORAGE, ALASKA 99501-35 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Drilling Manager Union Oil of California P.O. Box 196247 Anchorage, AK 99519-6247 Re: Swanson River Field, Tyonek 77-3 Gas Storage Pool, SCU 42-05Y Union Oil of California Permit No: 207-082 Surface Location: 3,283' FNL, 431' FEL, Sec. 5, T'7N, R9W, S.M. Bottomhole Location: 2,712' FNL, 494' FEL, Sec. 5, T7N, R9W, S.M. 39 Dear Mr. Brandenburg: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and operate the well is contingent upon issuance of a conservation order approving a spacing exception. Union Oil of California assumes the liability of any protest to the spacing exception that may occur. 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 revocati~r~ ur suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum fie ,' s ct at (907) 659-3607 (pager). DATED this ~ day of July, 2007 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~° _ Chevron ~ ~ May 31, 2007 ~ Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7~' Avenue Anchorage, Alaska 99501 ~ur~ o s zaa~ ~-iaska Oil & G~s Cnns. Commission : y.. Rnchorage _ Re: Application for Permit to Drill Swanson River Field, Soldotna Creek Unit #42-OSY Dear Mr. Maunder: Enclosed for your approval is a completed Application far a Permit to Drill (form 10-401) for the Swanson River Field SCU 42-OSY Gas Storage Well. Subject to AOGCC approval, it is our intention to drill a directional well to +/- 8,130/8,051' MDND. Run a T' production casing long string and then complete in the 77-3 sand with 3-1/2" tubing. We would like to request a variance from requirements of 20 AAC 25.035, to utilize a diverter vent line diameter of 12" to account for the smaller hole size, 12-1/4", we plan to drill out of the conductor. We are targeting a spud date of July 1 S~. Therefore, your earliest attention to this application will be greatly appreciated. If additional information is required, please contact either myself or Ms. Chantal Walsh at 263-7627. Sincerely, ~ C ~ Timothy C. Brandenburg Drilling Manager TCB: crw Attachments Cc: Well File ~.J Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O, Box 196427 Anchorage, AK 99519-6247 Fax 907 263 7884 ~~~l~~ V 4D Union Oil Company of California / A Chevron Company http:{/www.chevron,com . , . STATE OF ALASKA ~,~~~~ ~ ~~ ALA~ OIL AND GAS CONSERVATION COM~ON "~~c~ PERMIT TO DRILL 20 AAC 25.005 ~~~ 9~as~ /(~N ~~[/ ao;,_ o~ ~O 1 a. Type of Work: 1 b. Current Well Class: Exploratory ~ Development Oii ~ 1 c. Specify if well is proposed for: ~'j'~ ~O, Drill Q Redrill ~ Stratigraphic Test ~ Service Q Development Gas ~ ~ Coalbed Methane ~ Ga~ly~r '~ R e- e n t ry [] M u l t i p l e Z o n e ~ S i n g l e Z o n e ~ s S h a l e G a s ^ ~~~ o r C 2. Operator Name: 5. Bond: Blanket Q Single Well ~ 11. Well Name and mber: /s Union Oil Company of California Bond No. S~j~j CU 42-05Y ' 3. Address: 6. Proposed Depth: ~t~ 12. Field/Pool(s): PO Box 196247, Anchorage, AK 99519 MD: $130' n/~- 8051 ~ Swanson River Field/ Tyonek 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 431' FEL, 3283' FNL, Sec. 5, T7N, R9W, SM A028996 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 494' FEL, 2712' FNL, Sea 5, T7N, R9W, SM n/a Total Depth: 9. Acres in Property: 14. Distance to Nearest 494' FEL, 2712' FNL, Sea 5, T7N, R9W, SM 1120 Property: 2000~ 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Wefl SurFace: x- 341876 y- 2457937.6 ASP ZOtI@ 4' (Height above GL): 20.5 feet Within Pool: 385' from 42-05 16. Deviated wells: Kickoff depth: 4700 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 20 degrees Downhole: 4370 Surface: 1534 18. Casing Program: Specifications To p - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 16" 109# Weld/Drive 100' 0 0 100' 100' Drive 12-1/4" 9-5/8" 47# L-80 BTC 2500' 0 0 2500' 2500' 1,192 cu ft 8-1/2" 7" 26# L-80 BTC 8130' 0 0 8130' 8051' 694 cu ft 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry O perations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) : Effect. Depth MD (ft): Effect. Depth ND (ft): Junk (measured): Casing Length Size Cement Volume MD ND Conductor/Structural SurFace lntermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee Q BOP Sketch Q Drilling Program Q Time v. Depth Plot [] Shallow Hazard Analysis Q Property Plat Q Diverter Sketch Q 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. Contact Chanta/ Walsh 263-7627 Printed Name Timothy C. Brandenburg Title Drilling Manager ~- Signature Phone 907-263-7627 Date Commission Use Oniy Permit to Drill API Number: Permit Ap roval See cover letter for other Number: a~j'jQ ~ 50-1~ a0~$`„~~00~0~ Date: . . O requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: ~~y1 . ~j, U~S l b~~ ~~g Samples req'd: Yes^ No~ Mud log req'd: Yes~ fVo[~] l Y N ~ i 'd ^ ona o No Direct svy req : es HZS measures: Yes Q~c~~~o~•.S~rc,.cc~ "`'j S~C~. ~c, M~~"~`vr~ccfid-cyval'~ ~°'S . APPROVED BY THE COMMISSION DATE: ~ ~ ~ , COMMISSIONER O~j Form 10-401 Revised 12/2005 ~~~~~ n~~~ Submit' Duplic te 1 V ~~~~~.,/ ~~ ! • Maunder, Thomas E (DOA) From: Waish, Chantal -Petrotechnical [contractor] [WalshC@chevron.com] Sent: Tuesday, Juiy 03, 2007 11:09 AM To: Maunder, Thomas E (DOA) Subject: RE: 42-05Y-again AttacF~menfs: Directionai SCU42-05Y Vers 3.pdf ~ Directionai ~CU42-05Y Vers 3.., Tom, The 8th page of this attachment is the missing lower section of the spider map. Oops! Chantal -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 03, 2007 10:59 AM To: Walsh, Chantal -Petrotechnical [contractor] Subject: RE: 42-05Y--again Chantal, Thanks for the plan view of the penetrations. Further to my note of June 15, do you have additional pages of the spider plot? The one page in your application appears after the location survey and before the "Planned Wellpath Report". Call or message with any questions. Tom Maunder, PE AOGCC -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us) Sent: Friday, June 15, 2007 3:43 PM To: Chantal Walsh -Petrotechnical Subject: Re: 42-05Y--again Chantal, Nice to speak with you. With regard to the X and Y wells being the only penetrations of the 77-3 sand, is it possible to provide a plan view drawing that shows the relative well locations and the storage reservoir outline? I keep thinking of the 1/4 mile radius and if that works that would be fine. Thanks, Tom Thomas Maunder wrote, On 6/15/2007 2:44 PM: > Chantal, > I am reviewing the permit application and have a couple of questions. > l. There is only 1 page of the "spider map". Could you include the > additional pages. > 2. Is 42-05Y the only well in that area of the 77-3 sand? I have not > researched the storage order. I will need an assessment of cement for > any well penetrating the injection interval. If a well does not > penetrate the interval, a statement to that effect should be provided > Thanks in advance. Call or message with any questions. > Tom Maunder, PE > AOGCC > 1 • • Chevron Chevron ~ocation. Cook Inlet, Alaska (Kenai Penninsula) Slot. SCU42-OSY FiHd~. Soldotna Creek Unit Well~. SCU42-05Y Faci i: Sec 5 T7N R9W Wellb re~. SC 42-05Y r~.~ BAKER FIt~6NES INTEQ Plot rofarence wellpath is 42-05V Vers. #3 ___ Trua vartical depths are raferenced to Nabors 106E (RKB) Grid System: NAD27 / TM Alaska State Plane, Zone 4(5004). US feet Measured depths are refere~ced to Nabors 106E (RKB) North Reference: Tnie north __ _ ~ NaDOrs tO6E (RKB) to mean sea level: 173.5 feet ~ Scale: True distance __ __ _ ~ mean sea level to Mud line (Facility - Sec.S, T7N, R9V1q: 0 feet Depths aro in feet _ Coortlinates are in teat rafarenced to Slot Created by: MichWIG on 5/24/2007 Z 0 ~ ~ ~ m ~ Chevron C h ev ro n ~ LoCatiOn~ Cook I~let. Alaska (Kenai Penninsula) Sbt. SCU42-05Y Field. Soldotna Creek Unit Well SCU42-05V ~ Facili : Sec.S T7N R9W Wellbo~e: SCU 42-05Y ~ ~ ~y/'1.:r BA'l1~ Q HUGNES I1'~1'~'E(j Plot reference wellpath is 42-05Y Vers. #3 True vertical depths are referenced to Nabors 108E (RKB) Grid Systam: NAD27 / TM Alaska Stata Plana, Zone 4(5004), US feet Measured depths are referenced to Nabors 108E (RKB) North Reference: True north Nabors 106E (RKB) to mean sea level: 173.5 feet Scele: True distance mean sea level to Mud line (Faciliry - Sec.S, T7N, R9Wj: 0 feet Depths are in faet Coordinates are in feet referenced to Slot Created by: MichWiiG on 5/24/2007 Well Profile Data o•.yn cw~m.m ' rno ~n~ i~~ ~~~ rvo ~n~ ~ ~o=r H~n1 ~ i ~a~ E ~rt~ o~s ~vioonl I vs ~rt~ so.~.. . a.ro o00o o.w ss<.~oe . o.ao o.oo ~ ~ a.oo o.oo ~ Koa ~ aoo.oo o.ooo asa ~oe ~ noo.oo ~ o.au o.oo O.oo o.oo ~ - ~ EMOiB~Nd 58912J 19.825 35a>OB S611S] 169.06 _ -15fi6 ' I 169.78 ].00 _ '_ - ... __-.. Bee~ Yb Orov ex5) B1 19 B25 ' ~5e )09 51w 58 ]80 JB I 3310 I 78197 OOU EM iop )5]9.15 0.000 JS~~ae ]500.00 5&S.BO ' 3~.]5 1S0 58071 T ro t 1868.85 O.OW ]54.)~H 1I88_°A SB5.80 '.M25 0.00 58811 -. TD 1 C B1JU.00 0.000 15~.]OB BOS0.53 SB5.80 3~25 0.00 SBE.]1 ~ ~ 16in Condudor J EaSting (ft) I sow. , ~~n = ,oo n _ann .~Sn -~nn -150 -100 -50 650 t200 3000 ~ 3600 L Q m ~ V 4200 r 1 G) ~ 4800 ~ 5400 6600 7200 8400 7in l End lv ~sirt ~ ~ d 9.625in Casing L1 1. ~O BOGM (t9~5.0 b 200].0) aV: ~.~ FYp: 5%09.9 nT M~qmUC NeM 1~ 19.)B MPSSS Eoet of Tive NoM (at 05I1 t/06) ro ~o~sa.mwn m~m ra.v»m m r.ua .aa ie.~e d.P.e. qpp Begin Mgle Drop 350 Z O 3 ~ KOP ~ (O 300 ~ 2.00°/1 OOk 250 EnA of Build Z~ Begin Mgle Drop • Entl of Builtl 150 1.50°/100R 100 End of Drop Target ~ ~ ~ 7in Casing ~ n TD c KOP b 9.625in Casing N 16in Conductor 0 < SCU42-05Y -600 0 800 t20o 1800 Vertical Section (ft) ~""'"`""~°°" Azimuth 354.71 ° wiM raferonce 0.00 N. 0.00 E from wellhead ~ • Chevron LoCation~ Cook Inlet. Alaska (Kenal Penninsula) SIoL SCU42-05Y Field Sddotna Creek Unit Well: SCU42-OSY FaCilit ~. SeaS T7N R9W W Ilbore: SCU 42-0SY ~~~~ BAKER HVGNlS INTEQ Piot reference wellpath is 42-OSY Vers. #3 True vertical depths are referenced to Nabors 106E (RKB) Grid System: NAD27 / TM Alaska State Ptane, Zone 4(5004), US feet Measured depths are referenced to Nabors 108E (RKB) North Reference: True north Nabors 106E (RKB) to mean sea level: 173.5 feet Scale: True distance _ mean sea lavel to Mud line (Facility - Sec.S, T7N, R9V~: 0 feet Depths are in faet Coordinates are in feet referenced to Slot Created by: MichWIG on 5/24/2007 Traveling Cylinder Map North ~ s • • thevron ~ ~ June 28, 2007 Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7~' Avenue Anchorage, Alaska 99501 Re: Additional data for Permit to Drill ~I~~EfV~D ~1~,~~! 2 g Zn~7 ~tiaska f~ii & Gas Cons. Commission Anchorage Swanson River Field, Soldoma Creek Unit #42-OSY Dear Mr. Maunder: Please fmd attached a map of the 77-3 sand identifying the aerial extent and the wellbores drilled through it, and a write up about the Cement Isolation, across the gas storage sand, for the wells abandoned since the original filing of the Gas Storage Injection Order and for the newly drill SCU 42-OSX well as per your request. We are targeting a spud date of July 215`. Therefore, your earliest attention to this application will be greatly appreciated. If additional information is required, please contact me at 263-7627. Sincerely, ,~.a;' . ~ ~.r ~ y..~~__ ~ ~ ~r ~ Chantal Walsh CRW: crw Attachments Cc: Well File Union Oil Company of California / A Chevron Company Chantal Walsh Union Oil Company of California Petroleum Engineer P.O. Box 196427 Anchorage, AK 99519-6247 Fax 907 263 7627 http://www.chevron. com Structure: Showi ~real Extent of Sa 336725 346307 337000 338800 339000 340000 391000 392000 393000 344000 345000 346000 2961394 2961060 29se5ea 29s0eea 2959500 295seee 29se5e~ z95see0 ~95~5e0 z95~eee 2956590 z956eee 2955757 -~•-- -------------- ~------------------ ' , --------- ---*---------------- ----- ------- ; ~~e i .7SS~ ------- ~ B~ ; ; SCU 21-04 ~ ~ SCU 21A-04 ~ ~ ~ ~ ~~~ ~ ~ SCI~ 41-05 ,< SCU 3 I r ~ SCU 32-05 t ` ~' ` `. ~ f a.~ .~ r` scu 22-oa ,~ ~ ~ ~ ,~ ,~ cu sa~-o ~ ~ ~ ;~ ~ * ~SCU 12-04 0 ~ er~ ~ ~ ~p -~ ~ ~p ~ ~ ~ ~SCU 12A-O~j 's / m ~ ~r ~ s a s~ , e. n m~ e ~ ~ U 4 -tl51 ~ Uy 2-0 X ~i ~ S 22-04P6 C~1 ~2_05 Prop sed U 4 -0 S ,42105 ~,) ,~ ',, CU 3-05 ; ~ ; s 8 ' ~ '~ , , ~ ' ~ ` S U 1 C 4 04 ~ , ~ ~ ~ e ~ ~s , ~ ~ , ~ a ~s S U 43 -05 U 3-04 eB e ss ~e ~ , ~, CU 4A 0 ~ ~ ~ ~~ '` ' ~ ~ ~ - , B B , `? ~ ~ ~ ~S CU 1 05 SC 24A 5 B ~s ' ',~ e ~, ~ ~ e B`' •~S SCU 34-I y ~ \ U 2-05 ~ ' ' ` B `~? ` S 34 , SCU 3 -04 e~ i e i --7-------- --e I , , ~ -- -- - --- -- --- - -- - - - - - r ~ - - , -~-- ~ --- ----- ~ ---------~-_ l~~ 337000 338000 339000 340000 391000 392006 393000 344000 345000 346000 3367~8 346307 2961394 296]Be0 29se5ea z9seeea 295s5ea z95seee 29585e0 z95eeea 2957560 ~957000 2956590 z9s60ee 2955757 ~ • ~ i Integrity of wells within 77-3 Gas Storage Reservoir Addressed below are wells (within the 77-3 Gas Storage Reservoir) that have been worked over ar are newly drilled since the original submittal of the 77-3 Injection Order. A review of their cement isolation within the sand is listed below along with the mechanical integrity of the production casing of the active gas storage well. SCU 41-OS (Newly abandoned well~ ~~~, b a~ Cement Integrity: The abandonment of the wellbore was design to ensure isolation of the 77-3 sand. The wellbore was milled down to 7761'md (below the 77-3 sand ~ 7702' - 7725'), and 20 bbls of cement was squeezed. Additional isolation of the 77-3 sand was done by perforating the casing above the reservoir sand (~7630) and pumping an additiona122 bbls of cement. The 77-3 sand is isolated. The well is currently finalizing the surface abandonment phase. SCU 42A-OS (Phase 1 Abandonment Au~ust 2006) 1~0 -~(~(~, Cement Integrity: The wellbore was perforated into the 77-3 reservoir and 62 bbls of latex cement was laid across the 77-3 interval. The 77-3 sand is isolated. SCU 42B-OS (Phase 1 Abandonment August 2006) 1~ a-~~t~ Cement Integrity: The wellbore was perforated into the 77-3 reservoir at the time of abandonment. The perforation interval was squeezed with 20 bbls of cement. The 5-1/2" liner casing was milled from 7569' to 7598', and isolation of the 5-1/2" x 7-5/8" annulus was achieved by laying in and squeezing 16 bbls of Squeeze Crete cement across this interval. The 77-3 sand is isolated. SCU 42-OSX (drilled susnmer of 2006) a0 („ ~ C7~L ~ Cement Integrity: The Ultra Sonic Imaging Tool Cement Evaluation log shows very good bond across the 77-3 sand interval, good bond from 8130' (TD) to TOC at 3910'. The cement job for the well was done with 170 bbls of a Flex-stone cement blend. The 77-3 sand is isolated. Mechanical Integrity: There are no mechanical issues with the production casing of this well. • ~ ~ • v thevron Swan~on River Fie1d ~ SCU 42-O~Y Gas Starage Well ~ Gener~l arilling Procedure 1. Prepare Location. Set Cellar. Drill and drive 16" casing to +/- 100'. Install unitized well head. 2. MIRU ~ il Drilling Rig and Grind & Inject Unit. N~~~ +~~1 3. N/U and Function Test Diverter (see attached schematic) 4. P/U Drill Pipe and 12-1/4" BHA. 5. RIH and clean-out 16" conductor. 6. Directionally driil 12-1/4" hole with +/- 9.2 ppg water base mud to casing point at +/- 2500' (Note: depending upon drilling conditions, we may push the shoe depth to as deep as 3,300' MD). 7. Condition hole and POOH. 8. R/U and run 9-5/8" casing. 9. M/U and test cement lines. Circulate and then cement casing bringing cement back to surface. Bump top plug and test casing to 3,000 psi. 10. N/D Diverter. N/U and test BOPE to 3,000 psi/250 psi. 11. M/U 8-1/2" directional BHA c/w MWD and RIH. Drill out float equipment, rat hole and 20' of new formation. Pull back into the casing and conduct a leak-off test (Note: if the formation doesn't leak-off by a 15.5 ppg EMW, the test may be suspended). 12. Directionally drill 8-1 /2" hole to TD at +/- 8,165' with Water Base Mud as high as +/-12.5 ppg depending upon hole conditions. 13. Condition hole and POOH. 14. R/U and run open hole logging suite from TD to the 9-5/8" shoe. 15. Make conditioning run with bit if required by hole conditions. 16. R/U and Run 7" casing to below the 77-3 sand. 17. Circulate and cement casing utilizing caliper hole data bringing the cement top to +/- 4,000' TVD. Bump p~ug ~r~ #e~t~i~g tv 5,0~ psi. 18. RIH with drill pipe and casing clean-out assembly. Displace well lease water. POOH. 19. R/U E-Line and make a cement evaluation logging run. 20. R/U and run TCP gun assembly, Hydraulic Packer and 3-1/2" tubing completion string. Make correlation run with E-Line, space-out and land hanger. General Procedure SCU 42-05Y 1 . .' , ~ ~ Ghevron Swanson River Field SCU 42-05Y Gas Stor~ge Well ~ General Drilling Procedure 21. Set Hydraulic packer with plug landed in nipple profile. Recover setting plug. 22. RIH and shift sliding sleeve open. Circulate thru the sleeve with packer fluid and then under balance tubing with Nitrogen cushion. RIH and shift sliding sleeve closed. 23. Fire TCP guns and flow well to clean-up. 24. N/D BOPE. N/U and test tree. 25. Release Rig. General Procedure SCU 42-05Y 2 • ~ Chevron i Welibore Schematic: SCU 42-05Y Proposed Well Name: SCU 42-05Y Operator: Union Oil Company of California Field: Swanson River Unit: Soldotna Creek API: Permit: Well Status: Gas Storage RKB: 171.5' above MSL, 20.5' above GL TD/TVD: 8,155' MD/8,055' ND PBTDlPBND: n/a Casin Detail Size Wt Grade Type Top (FT) Btm (FT) Length (FT) 16" 109# Weld/Drive 0.00 100 100 9-5/8" 47# L-80 BTC 0.00 3,000 3,000 7" 26# L-80 BTC 0.00 8,130 8,130 Tubin Detail Size Wt Grade Type Top (F~ Btrn (Fn Length (FT) 3-1/2" 9.2# L-80 Atlas Bradford TC-2 0.00 7,780 7,780 Jewel Detail 1 Side Pocket Chemical Injection Mandrel 2,500 2 CMD Sliding Sleeve 7,730 3 BOT SAB-3 Perm. Packer with a K-Anchor and Mill out extension 7,780 4 XN-Nipple 7,800 5 3-1/2" Ported Sub 7,820 6 3-1/2" IBT x 2-7/8" EUE XO ~,821 7 Full Joint 2-7/8" EUE Tubing ~,8z2 ~ 8 2-7/8" Wire Line Re-Entry Guide (Halliburton Automatic Release Assy.) 7,860 9 Top af Dropped TCP Assy. (~a' long) $,~~ 5 Perforation Detail 2one SPF Date Top (F~ Btm (FT) Len th (FT) 77-3 5 -7880 ~ 7890 ~10' Last Revised: 4/20/2007 Revised By: CRW ~ ,' ~ ~ T8N T7N `~~~~~~~~11 ~~~~ oF A~qs~~~~ ~ '~Q''~~ ••~ ~ ~.~ ' ~ ~ ~'~*~~~ .. *.:~.49 ~ .................., ~ ........ ...............:.....~ j, c~;M. SCOTT McLANE ~~ i I,~ 4928-S .•~+ ~ ~`~o'~~~~........-.~-~~ .. ~r '~~5~«~~- `~ ~~ 1'~~~\\~~``~ -- EDGE OF PAD ~_ ~ I SECTION LINE (NOT TO SCALE) ~32 .33 514 AS-STAKED WELL SCU42-05Y SWANSON RIVER FIELD I PAD 42-05 J GRID N:2457937.567 Z GRID E:341876.366 I W Z LL LATITUDE:60°43'29.518'N ~ LONGI111DE:150°52'59.484'W J CD ASP ZONE 4 NAD27 Z o m ~~_~,~ x FNL = 3283' ' E' ~ (NAVD88) ELEV =153.0 W ~ SECTION 5, TOWN3HIP 7N, I~ W RANGE 9W, SM AK ~ _~- ~ I , I WELL "Y" 431' FEL ~ ~ ~ ~ / ~ a~ EDGE OF PAQ / ~ ~`~. ~" ~~~ i '~~. SRF 42 - 05 PAD NOTES 1) BASIS OF COORDINATES: NGS CORS STATION "KEN 1" NAD 27 ALASKA STATE PLANE ZONE 4. 2)BASIS OF ELEVATION: NGS BM Q79 RESET NAVD88. 3) SECTION LINE OFFSETS COMPUTED FROM C Y~ SEC 5 FOUNO AND BLM RECORD DATA. ~ ~ SRF PAD 42-05Y WELL APPLICANT: AS-STAKED SURFACE LOCATION V NOCA L SWANSON RIVER GAS FIELD LOCATION: SECTION 5, TOWNSHiP ENGINEERING - TESTING 7 NORTH, RANGE 9 WEST, ~~ SURVEYING - MAPPING SEWARD MERIDIAN ALASKA P.O. BOX 468 909 W. 9th Avenue ~ SOLDOTNA, AK. 99669 ~pB NO. 073043 Anchorage, AK 99519-7685 VOICE: (907) 283-4218 FAX: (9U7) 283-3265 ~~ WVWV.MCLANECG.COM p~: 073043 Date: 5/17/07 FIGURE: 1 ~ • Chevron Location: Cook Inlet, Alaska (Kenai Penninsula) Slot: SCU42-05Y Field: SoWotna Creek Unil Well: SCUd2-05Y Facili : Sec.S T7N R9W Wellbore: SCU 4-05Y ~~.~ BAKER Nu~N~s INTEQ Plot reference wellpath is 42-05Y Vers. #3 --- --- . . .--- --. _ .. True vertical depths are referenced to Nabors 106E (RKB) Grid System: NAD27 1 TM Alaska State Piane, Zone 4(5004), US feet Measured depths are referenced to Nabors 108E (RKB) North Reference: True north ._ _ _ Nabors 10fiE (RKB) to mean sea level: 173.5 feet Scale: True distance __ mean sea level to Mud line (Facility - Sec.S, T7N, R9V1~: 0 feet Depths are in feet _ Coordinates are in feet referenced to Slot Created by: MichVNIG on 5/24/2007 196 1B0 186 150 195 120 105 Z 0 90 7 ~ m ~ 75 80 45 90 ~ 0 .~ G,r, r ~ Easting (ft) ~ thevron pianned Wellpath Report ~~ 42-OSY Vers. #3 ~ Page 1 of 4 INTEQ Operator Chevron iSlot SCU42-OSY . _ _ _. _ . _ _ _ ___ _._ Area Cook Inlet, Alaska (Kenai Penninsula) _ _ Well SCU42-OSY _ _ _ _ ___ _ _ _ ___ Field Soldotna Creek Unit Wellbore SCU 42-05Y Facility Sec.S, T7N, R9W _ 'Projection System NAD27 / TM Alaska State Plane, Zone 4(5004), US feet Softwaze System We1lArchitectTM 1.2 North Reference True User MichWilG _ Scale 0.999928 _._ _ Report Generated AS/24/07 at 15:12:21 , Wellbore last revised 05/Ol/07 Database/Source file WA Anchorage/SCU_42-OSY.xml Local coordinates Grid coordinates Geographic coordinates North [feetJ East [feet] _ __ Easting [US feet] Northing [US feet] Latitude [°] I,ongitude (°] _ _ _ Slot Location i 979.30 -439.10 341876.37 2457937.57 60 43 29.516N 150 52 59.494W Facility Reference Pt 342288.86 2455952.70 60 43 10.025N 150 52 50.666W Field Reference Pt 347568.07 24558$2.99 60 43 10.024N 150 51 04.527W ' Calculation method Minimum curvature Nabors 106E (RKB) to Facility Vertical Datum 173.50 feet ._ _ ___ FIorizontal Reference Pt Slot __ _. Nabors 106E (RK$) to mean sea, ievel 173.50 feet Vertical Reference Pt Nabors 106E (RKB) _ __ _ Facility Vertical Datum to Mud Line (Facility) 0.00 feet _ MD Reference Pt Nabors 106E (RKB) Section Origin N 0.00, E 0.00 ft Field Vertical Reference mean sea level Section Azimuth 354.71° • ~~~ BAKER NYt~MES ~ tnevrvn planned Wellpath Report 42-05Y Vers. #3 ~ Page 2 of 4 • ~~. BAKER H1~6MES INTEQ Operator Chevron Slot SCU42-OSY __ _ _ _ _ __ _ Area Cook Inlet, Alaska (Kenai Penninsula) _. _ _ _ Well SCU42-OSY Field Soldotna Creek Unit Wellbore SCU 42-OSY Facility Sec.S, T7N, R9W __ _ _ _ WELLPATH DATA (87 stations) fi= interpolated/eatrapolated statian __ _ _ MD Incliaation Aziaruth TVD Vert Sect North ' F.ast Grid East Grid North DLS Build RAte Tnrn Rate Design [feet] [°] (°J [feet~ [teet~ [feet] ' [feet] _ [us survey feet] _ [us survey feet] . _ [°/100R] [°/100ft] [°/100ft] Comments 0.00 0.000 354.709 0.00 0.00 0.00 0.00 341876.37 2457937.57 0.00 0.00 O.OO Tie On 100.00fi 0.000 0.000 100.00 0.00 0.00 0.00 341876.37 2457937.57 0.00 0.00 0.00' 200.OOt 0.000 0.000 200.00 0.00 0.00 0.00 341876.37 2457937.57 0.00 0.00' 0.00' 300.OOi' 0.000' 0.000 300.00 0.00 ' 0.00 0.00 34187637 2457937.57 0.00 0.00 0.00 400.OOj' 0.000 0.000 400.00 0.00 O.UO 0.00 3418'76.37 2457937.57 0:00 ' 0.t)d O.QQ 500.00 j- 0.000 0.000 500.00 0.00 0.00 0.00 341876.37 2457937.57 0.00 0.00' 0.00 600.00 j~ 0.000 0.000 600.00 0.00 0.00 0.00 34187637 2457937.57 0.00 0.00 0.00 700.OOt 0.000 0.000 700.00 0.00 0.00 0.00 341876.37 ' 2457937.57 0.00 0.00 0.00 _ ' 800.00 j' 0.000 0.000 _._ 800.00 0.00 ' _ 0.00 0.00 _ 341876.37 _. 2457937.57 0.00 0.00 0.00 9(~.00 j' ' 0.000 U.000 ' 900.Q0 '(1.00 O.OQ 0.00 341876:37 2457937.57 0;~ 0.0p O.t10 1000.00 j~ 0.000 0.000 1000.00 ' 0.00 0.00 0.00 341876.37 2457937.57 0.00 0.00 0.00 1100.OOt 0.000 0.000 1100.00 0.00 ' 0.00 0.00 34187637 2457937.57 0.00 0.00 0.00 1200.00 fi 0.000 0.000 1200.00 0.00 0.00 0.00 341876.37 2457937.57 . 0.00 0.00 0.00; 1300.OOt 0.000 0.000 1300.00 0.00 ' 0.00 0.00 341876.37 . . 2457937.57 0.00 0.00 0.00 14Q0.00'~; 0.000 O.OOt} 140f1.QQ 0.00 0.00 OAO 3418?6:37 2457937.5? 0:00 ' 0.00 : Q.W 1500.00j' 0.000 0.000 1500.00 0.00 0.00 ` 0.00 341876.37 2457937.57 0.00 0.00 0.00' 1600.00 j~ 0_000 0.000 1600.00 0.00 0.00 0.00 341876.37 2457937.57 0.00 0.00 0.00 1700.00~' 0.000 0.000 1700.00 0.00 0.00 ' 0.00 ' 341876.37 245793'1.57 0.00 0.00 0.00 1800.00~ 0.000 0.000 1800.00 _ 0.00 . 0.00 0.00 _ _ 341876.37 ___ . 2457937.57 0.00 0.00 0.00 19QO.OO j~ ' 0.000 O.Q00 1940.OE1 ` 0.00 ' 0.00 0.00 341876.3? 2457937.57 Q.00 0.00 ; 0.00 ' 2000.00 j' 0.000 0.000 2000.00 0.00 0.00 ' 0.00 34l 87637 2457937.57 0.00 _ 0.00 0.00 _ 2100.OOj~ __ 0.000 __ 0.000 __ 2100.00 _ 0.00 0.00' 0.00 341876.37 __ 2457937.57 . 0.00 0.00 0.00 2200.00~' 0.000 0.000 2200.00 0.00 0.00 ' 0.00 341876.37 2457937.57 , 0.00 0.00 0.00 2300.OOfi _ 0.000 _ ___ 0.000 _ 2300.00 0.00 0.00 ' 0.00 341876.37 2457937.57 0.00 0.00 0.00 Z400.00~ 0.000 0.000 24tN3.04 Q.00 ° 0.00 0.00 3418~6.3~ 2457937.5? 0.~ 0.00 Q.00 2500.00~' 0.000 0.000 2500.00 0.00 0.00 0.00 341876.37 2457937.57 ' 0.00 0.00 0.00 2600.OOt 0.000 0.000 2b00.00 ' 0.00 0.00 0.00 341876.37 2457937_57 0.00 0.00 0.00 : 2700.OOt 0.000 0.000 2700.00 , 0.00 0.00 ' 0.00 341876.37 : 2457937.57 0.00 0.00 0.00 2800.OOt 0.000 0.000 2800.00 0.00 0.00 0.00 341876.37 2457937.57 0.00 0.00' 0.00 2900.00 j~ O.OOQ 0.000 2900.U0 ~.00 '' O.fb Q.00 341876.37 2457937.5? 0:00 0,00 '. O.OU 3000.OOfi 0.000 0.000' 3000.00' 0.00 0.00 0.00 341876.37 _ 2457937.57 _ 4.00 0.00 0.00! _ __ 3100.00~' 0.000 _ 0.000 _ 3100.00 0.00 ' 0.00 0.00 34187637 2457937.57 0.00 0.00' 0.00 3200.00 j" 0.000 0.000 3200.00 ` 0.00 ' 0.00 0.00 341876.37 2457937.57 0.00 0.00 0.00i 3300.00 fi 0.000 0.000 3300.00 0.00 0.00 0.00 341876.37 2457937.57 0.00 0.00 0.00 3400.00~ 0.000 0.000 34~.00 O.OQ O.UO 0.00 341876:37 2457937:57 O:OtI ' O.fM~ ; 0.4~ 3500.OOj' 0.000 0.000 3500.00 0.00 0.00 0.00 341876.37 2457937.57 _ . 0.00 0.00' _ 0.00 _ 3600.OOt 0.000 0.000 _ __. 3600.00 ' _._ 0.00 0.00 0.00 341876.37 _ _ _ 245793~.57 0.00 0.00 0.00 _ 3700.00~ 0.000 _ _ 0.000 _ __ .._ 3700.00 _ . __ 0.00 ' 0.00 0.00 . 341876.37 2457937.57 _ 0.00 0.00 0.00 ' 3800.00 j~' 0.000 0.000 3800.00 : 0.00 0.00 i 0.00 34187637 2457937.57 0.00 0.00' 0.00 ~ thevron planned Wellpath Report ~~ 42-05Y Vers. #3 ~ ~'age 3 of 4 ~ ~.~ BAKER i~1~1t~iNES INTEQ Operator 'Chevron Slot SCU42-05Y _ _ Area Cook Inlet, Alaska (Kenai Penninsula) Well __ SCU42-OSY Pield Soldotna Creek Unit __ Wellbore _ SCU 42-OSY _ _ Facility Sec.S, T7N, R9W _ WELLPATH DATA (87 stations) _ ~= interpolated/extrapolated station MD Ioclination Azimuth TVD Vert Sat Nort6 East Grid East Grid North DI,S Bnild Rate Turo Rate Desiga [feet] [°] [°] [feet] [feetj [feet] [feet] _ [us survey feetJ [us survey feet~ [°llOOft] __ _ _ (°/100ft] [°/100R] Comments 4000.00 j' 0.000 0.000 4000.00 0.00 0.00 0.00 34187637 2457937.57 0.00 0.00 0.00 4100.00 j~ 0.000 0.000 4100.00 0.00 0.00 0.00 341876.37 2457937.57 0.00 0.00 0.00 4200.00~' 0.000 0.000 4200.00 ___ 0.00 _ _ 0.00 0.00 _ 34187637 _ 2457937.57 0.00 0.00 0.00 4300.00~ 0.000 0.000 4300.00 ~_ 0.00 ' 0.00 0.00 341876.37 2457937.57 0.00 0.00 0.00 4400.00 j' O.U00 OA00 4400.00 0.00 0.00 0.00 341876.37 245793'1.5'3 0.00 0.~ U.00 4500.00~ 0.000 0.000 4500.00 0.00 0.00 0.00 34187637 ' 2457937.57 0.00 0.00 0.00 4600.OOt 0.000 0.000 4600.00 0.00 0.00 0.00 341876.37 2457937.57 0.00 ' 0.00 0.00 4700.00 0.000 354.709 4700.00 0.00 0.00 ' 0.00 ' 34187637 _ 2457937.57 0.00 0.00 O.OO KOP . 4800.00~' __ 2.000 354.709 4799.98 1.75 _ _ 1J4 -0.16 34187G.23 _ _ _ 2457939.31 2.00 2.00 0.00 4900.OOt ' 4.OQ0' 354.709 4899.84 6.9$ 6.95 -O.b4 34i875.$2 2457944.52 2.00 ' 2.00 Q.UO 5000.00~ 6.000 354.709 4999.45 15.69 15.63 -1.45 341875.13 2457953.21 2.00 _ 2.00 0.00 S 100.00 fi 8.000 354.709 5098.70 27.88 27.76 -2.57 341874.17 2457965.36 2.00 2.00 0.00 5200.00~' 10.000 354.709 5197.47 43.52 43.34 -4.01 341872.94 2457980.95 __ 2.00 2.00 0.00 5300.00 j' 12.000 354.709 5295.62 62.60 62.34 -5.77 341871.43 2457999.97 2.00 2.00 0.00 5400.OQ j~ 14.000 354.709 5393:06 85.14 84.73 =7.85 341869.66 2458622.39 ' 2.00 2.00 Q.00 SSOO.OOt 16.000 354.709 5489.64 110.98 1 t0.50 -10.23 341867.62 2458048.19 2A0 2.00 OAO 5600.00j~ 18.000 354.709 5585.27 140.21 139.62 -12.93 341865.32 2458077.33 2.00 2.00 0.00 5691.23 19.825 354.709 5671.57 169.78 __ t69.06 -15.66 ' 341862.99 _ _. 2458106.81 ' 2.00 2.00 O.OO End of Build 5700.00# 19.825 354.709 5679.82 _ 172.76 172A2 -15.93 _ ' 341862.75 2458109.77 0.00 0.00 0.00 5800.00~ : 19.825`354.709 5773.89 206.67 205.19 -19.06 341860.08 2458143.58 0.00 O.OU O.OU 5900.00 j' 19.825 354.709 5867.97 __. __ 240.58 239.56 -22.19 _ 341857.40 2458177.38 0.00 _ 0.00 0.00 6000.00 j' 19.825 354.709 5962.04 274.50 __ 27333 -25.31 341854.73 . _ _ _ 2458211.19 ; 0.00 0.00 0.00 6100.OOt 19.825 354.709 6056.11 308.41 307.10 -28.44 341852.06 2458245.00 ` 0.00 0.00 0.00 6200.00 fi 19.825 354.709 6150.19 342.33 340.87 -31.57 341849.39 2458278.80 0.00 0.00 0.00 6257.82 19.825'354.7U9 6204.58 362.93 360.39 -33.38 341847.84' 24~8298.35 ; O.OQ 0.00 O.OOBegin:AagteDrop 6300.00~ 19192 354.709 G24434 376.02 ' 374.42 -34.67 341846.73 ' 2458312.39 " 1.50 -1.50 0.00' 6400.00~ 17.692' 354.709 6339.20 __. 407.65 405.92 -37.59 . _ 341844.24' 2458343.92 1.50 -1.50 0.00 6500.00~', 16.192 354.709 G434.86 436.79 434.93 ;-40.28 ' 341841.94 ' 2458372.97 1.50 -1.50 0.00 6600.00 j~' _~_ 14.692 354.709 6531.25 463.42 . 461.44 -42.73 341839.84 2458399.51 1.50 -1.50 0.00 6700.OQ'~ I 13.192 354.709 6628.30 487.51 485.43 -44.96 341&37.94 2458423.52 . 1.50 -1.50 0.00 6800.OOt 11.692 354.709 6725.95 _ 509.05 _._ 506.89 -46.94 341836.25 ._ 2458445.00 _ __ _. 1.50 _ -1.50' 0.00 6900.OOj'' 10.192 354.709 6824.13 528.04 525.79 -48.69 _ _ 341834.75 _ 2458463.92 1.50 -1.50' 0.00 7000.OOj'' 8.692I354.709 6922.77 544.44 542.12 -50.21 341833.46 2458480.27 1.50 -1.50 O.OQ 7100.00 j'' 7.192 354.'709 7021.81 558.26 555.88 -5 L48 341832.37 2458494.04 1.50 __ -1.50' 0.00 72pU.00'~ 5.692 354,709 7IZI.I7 569.4'7 567.03 -52.51 34I~3I.48 2458505.23 1.SQ -1.50 O.OQ 7300.OOj' 4.192 354.709 7220.80 _ 578.09 _ _. 575.63 -53.31 341830.81 2458513.81 _ 1.50 ' -1.50' 0.00 7400.00~' 2.692 354.709 7320.61 584.09 __,_ . 581.60 -53.86 _ 341830.33 _.. 2458519.80 1.50 -1.50' 0.00 _ _ 7500.OOj~ 1.192 354.709 7420.55 587.48 584.98 -54.17 341830.07 2458523.18 1.50 -1.50 0.00 7579.45 ' 0.000; 354.709 7500.00 588.31 585.80 ;-54.25 ' 341830.00 2458524.00 i 1.50 -1.50'' O.OOEnd of Drop ~ • Chevron planned Well ath Re ort ~~~~ ~ p p BAKER 42-05Y Vers. #3 NVGNES ~ Page 4 of 4 INTEQ Operator Chevron Slot SCU42-OSY Area Cook lnlet, Alaska (Kenai Penninsula) Well SCU42-OSY Field Soldotna Creek Unit Wellbore SCU 42-OSY Facility Sec.S, T7N, R9W WELLPATH DATA (87 stations) j~ = interpolated/extra polated station MD Inclination Azimuth TVD Vert Sect North M:ast Grid F.ast Grid North DLS Build Rrte 'furn Rate Design ~feet~ [°~ [°~ (Ceet~ ~feet~ [feet~ ~feet~ [us survey feet~ ~us survey feet~ (°/100R) ~°/IOOtt~ ~°/100ft~ Commenfs 7700.OOt 0.000 0.000 7620.55 58831 585.80 -54.25 341830.00 2458524.00 0.00 0.00 0.00 7800.OOt 0.000 0.000 7720.55 58831 585.80 -54.25 341830.00 2458524.00 0.00 0.00 0.00 7868.95 0.000 354.709 7789.50~ 588.31 585.80 -54.25 341830.00 2458524.00 0.00 0.00 O.OOTarget 7900.00~' 0.000 0.000 7820.55 588.31 585.80 -5425 341830.00 2458524.00 0.00 0.00 0.00 8000.OOj' 0.000 0.000 7920.55 588.31 585.80 -54.25 341830.00 2458524.00 0.00 0.00 0.00 8100.OOt 0.000 0.000 8020.55 588.31 585.80 -54.25 341830.00 2458524.00 0.00 0.00 0.00 8130.00 0.000 354.709 8050.55 588.31 585.80 -54.25 341830.00 2458524.00 0.00 0.00 0.00 "I'D - 7" Csg Pt FiOI.F. &(:ASING SECTIONS Ref Wellbore: SCU 42-OSY Ref Wellpath: 42-OSY Vers. #3 String/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start H:/W End N/S End E/W [feet] [feet~ [feetJ ~feet~ [feet] [feet] [feetJ [feet~ (feetJ 16in Conductor 0.00 100.00 100.00 0.00 100.00 0.00 0.00 0.00 0.00 9.625in Casing Surface 0.00 3000.00 3000.00 0.00 3000.00 0.00 0.00 0.00 0.00 L2.25in Open fIole 0.00 3000.00 3000.00 0.00 3000.00 0.00 0.00 0.00 0.00 8.Sin Open E-Iolc 0.00 8130.00 8130.00 0.00 8050.55 0.00 0.00 585.80 -54.25 7in Casing Production 0.00 8130.00 8130.00 0.00 8050.55 0.00 0.00 585.80 -54.25 TAR(~ETS Name MD TVD North East Grid F.ast Crid Nortli Latitude I,ongitude Sdape [feet~ ~feet~ [feet~ [feet~ [us survey feet~ [us survey feet~ [°~ [°] 1) Penetration for we113 16- 7868.95 7789.50 585.80 -54.25 341830.00 2458524.00 60 43 35.285N 150 53 00.585W polygon Mar-07 SURVEY PROGItAM Ref Wellbore: SCU 42-OSY Ref Wellpath: 42-OSY Vers. #3 Start MD End Mll Positional Uncertainty Model I.og Name/Comment Wellbore [feet~ [feet] 0.00 3000.00 Navi'frak (Standard) SCU 42-OSY 3000.00 8130.OONaviTrak (Standard) SCU 42-OSY , ~ • Chevron ~//'~ ~ Wellpath Design Summary Report BAKER Wellpath: 42-05Y Vers. #3 N~IGMES ~ Page 1 of 2 INTEQ Operator Chevron Slot SCU42-OSY Area Cook Inlet, Alaska (Kenai Penninsula) Well SCU42-OSY Field Soldotna Creek Unit Wetlbore SCU 42-OSY Facility Sec.S, T7N, R9W Projection System NAD27 / TM Alaska State Plane, Zone 4(5004), US feet Software Systcm WellArchitectTM 1.2 North Reference True User MichWilG Scalc 0.999928 Report Generated OS/24/07 at 15:15:52 Wellbore last revised 05/O1/07 Database/Source file WA_Anchorage/SCU_42-05Y.xml 1 Local coordinates Grid coordinates Geographic coordinates North (feet~ East [feetJ Easting [US feet~ Northing [US feetj Latitude [°~ Longitude [°~ Slot Location 197930 -439.10 341876.37 2457937.57 b0 43 29.516N 150 52 59.494W Facility Reference Pt Field Reference Pt 342288.86 2455952.70 60 43 10.025N 150 52 50.666W 347568.07 2455882.99 60 43 10.024N 150 S l 04.527W Calculation method Minimum curvature Nabors 106E (RKB) to Facility Vertical Datum 173.50 feet Horizontal Reference Pt Slot Nabors IOGE (RKB) to mean sea level 173.50 feet Vertical Reference Pt Nabors 106F. (RKB) Facility Vertical Datum to Mud Line (Facility) 0.00 feet MD Reference Pt Nabors 106E (RKB) Field Vertical Reference mean sea level WELLPATH MD DATA (7 stati Inclinatioo ons) Azimuth TVD Vert Sect ~teet] [°J [°J [feet] (feet) 0.00 0.000 354.709 0.00 0.00 4700.00 0.000 354.709 4700.00 0.00 569 L23 19.825 354.709 5671.57 169.78 6257.82 19.825 354.709 6204.58 3G1.93 7579.45 0.000 354.709 7500.00 588.31 7868.95 0.000 354.709 7789.501 588.31 8130.00 0.000 354.709 8050.55 588.31 Ref Wellbore: SCU 42-OSY Re String/Diameter Start MD F.nd MD Interval Start TVD [feet] [feet~ [teet] [feet] 16in Conductor 0.00 100.00 100.00 0. 9.625in Casing Surface 0.00 _ 3000.00 3000.00 0. _. 12.25in Open Hole 0.00 3000.00 3000.00 0. S.Sin Open Hole 0.00 8130.00 8130.00 0. 7in Casing Production 0.00 8130.00 8130.00 0. North F.ast DL.S Design [feet~ ~feet~ (°/100ft] Comments 0.00 0.00 0.00 Tie On 0.00 0.00 0.00 KOP 1G9.06 -15.66 2.00 f;nd of Build 360.39 -3338 0.00 Begin Angle Drop 585.80 -54.25 1.50 End of Drop 585.80 -54.25 0.00 Target 585.80 -54.25 0.00 "fD - 7" Csg Pt End'CVD Start N/S Start E/W [feet] (feet~ [feet] 0 100.00 0.00 0.00 0 3000.00 0.00 0.00 0 3000.00 0.00 0.00 0 8050.55 0.00 0.00 0 SO50.55 0.00 0 0 0 0 0.00 0 Eod N/S End ~:/W ~feetJ [feet~ 0.00 0.00 0.00 0.00 0.00 0.00 585.80 -54.25 585.80 -54.25 ~ ~ Chevron ~ Wellpath Design Summary Report ~ Wellpath: 42-OSY Vers. #3 Page 2 of 2 Operator Chevron Area Cook Inlet, Alaska (Kenai Penninsula) I'ield Soldotna Creek Unit Faciliry Sec.S, T7N, It9W TARGETS ri.~ BAKER MYGI~IES INTEQ Name MD TVD rorth East Grid F,ast Grid North I.atitude Longitude Shape [feet~ (feet] [feet] [feetJ [us survey feetj [us survey fect) [o~ ~o~ 1) Penetration for weli 3 16- 7868.95 7789.50 585.80 -54.25 341830.00 2458524.00 60 43 35.285N 150 53 00.585 W polygon Ma r-07 SURVEY PROGRAYI Ref Wellbore: SCU ~32-OSY Ref Wellpath: 42-OSY Vers. #3 Start MD F.nd MD Positional Uncertainty Model I.og Name/Comment Wellbore (feet~ [feetJ 0.00 3000.00 Navi'I'rak (Standazd) SCU 42-OSY ~ 3000.00 8130.00 NaviTrak (Standard) SCU 42-OSY ! Wellbore SCU 42-OSY • ~ ATTAf I-111A~AIT 1 , ~ ~ - -.. ; ~ A028399 t ~~ SNAN30N RIVER FISLD ° °.ZS °.` ' ~ un;on oa coe~paey - ~ °~ ~~~ Proposed Location 4 2- ~ 5 Y Al~+k~ .".1 H^ f~'.aMNLM {. 1aV~"~ • • I"'~~/"'ili ~ IYi ~ i V~ 2 31 ~ ~ scU az-en SCU 332 ~A . . ._:.: 2SSH-C4 IO .~ ~. 8 i7 ~_ 33 34 . . ~ -- ~ ~= ---~ ... ~ ~ -. ~ ~ 7, - ' 1 !~ SCU 23A-G9 SCU 24A•09 ~ ~.u. _: 16 Cwwes SY~IANS~i RIVSIZ FISLD o ~sa i,sco s.oa ~ L7tionOdCampeny p=p~p8@C~ I.OQ8t10A 42-05Y Fe.e of Gk"JOmia 1 ~7~ 1'lR119 R8c' • 11S lllaxka s:ata e1a:c Yone ~. ttAU:.1 32 ~ -~ ° __" i ~':'"---~: - __ __ -, ~ ~ ~ ~ .~~ , ~~~ ~~~ s~ . ~~ ,~ ~~ ~ .~ ~ ~~ ~; , ' ~s r.~ u ~ . ~ ~~ ;~~~~~" ;.' . ~~yf'. ~,j`~~~~ ~ ~ . ~ f • ~ ~ f~~ ~.= t ' w w'~" i ~ j ~ . ! 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S ~,- ~ . .~ i ~ ~' 4~ ~~~{~ _.~`L~'i ~ t ~i . f."~ 14i +~,t+~r'4 ,, ~ ~'~ ~ , .v ~ ~~ .r ~ . . .. ; ~_ • !!~ ~~, -y~~ ~}i'a' ~, / ~ ~,~,; ~~'t„~~~~ r.k. ~' ~ ~"~~ .-~ ~.. ~k' `,~~'.~a-N~~+~ '' ~~w - . ~~~~`. .. . ~ .~.~ e'4a~ ' ~ f ~ # t 4 ``e'~ ~ . 1~ .. ~~ . ...-. .,. . . . •..~~~~ .fr.'a~1V~t ~_. ..~° . . i ~' ~~"'~O" 3WAN3~ RIVER FIFiLD o so ioo zoo ~ V111011 ~II ~Ofll~fl~ F~~i ~ OfC~lifOmie Proposed Location 42-O~SiY wlaxta scat~ elene xoa~ ~. .uo2~ ESTIMATED GEOLOGIC TOPS AND CORRELATIONS SCU 42-05Y # 3 location- estimated 6' deeper than X locafion (FINAL DR1LL LOCAT/ON) 42-05Y Markers MD TVD NDRKB Litholo y Sterlin B 1243 1243 To Belu a 3343 3343 Mid Belu a 4478 4478 Mid Belu a Sand 1 4769 4769 T onek 5379 5372 55-8ST 5633 5626 D 1 CT 5747 5721 56-9ST 5794 5768 64-5ST 6537 6472 68-0 SB 69C7 6831 oCJ-7 C.~ 7~'1~8 o5b~ ~ ( IUl°TaC@OUS SIIiSiOi12 7~-1 CT 7io4' ~ 7~8o j tuTraceous cla s~ona 70-2STE 7175 E 7097 ~ tuffaceous siftstonz, ~ecomin sandier wiih de tn 70-8 Cl' ~ 7243 7163 furiaceous siltstona Yo sandsione 73-5 C f 7492 7412 75-7 CT 7688 7608 „ _ , ,. I D 8130 8049 • • ~ • Chevron Swanson River Fiefd ~ Weil SCU 42-05Y Cement Program 13-3/8" Casinq (Air Drilled to +/-100') Note: This string is only for structural support of the wellhead. 9-5/8" Casinq j12-1/4" Hole to 2,500' MD): Cement volume based on open hole volume plus 50%, shoe joints and annulus. The job will consist of a lead and tail and cement will be brought to surface. The estimated total volume is as follows: Lead: 2,000' X 0.3132 cuftlft (12-1/4" x 9-5/8") X 1.5 = 940 cuft = 475 sxs (1.98 yield) Tail: 500' X 0.3132 cuft/ft (12-1/4" x 9-5/8") X 1.5 = 235 cuft = 203 sxs (1.16 yield) 40' shoe joint X 0.4110 cuft/ft TOTAL: 940 + 235 + 17 = 1,192 cuft or 685 sxs 7" Casinq (8-1/2" Hole to 8,164' MD): = 17 cuft = 7 sxs (1.16 yield) Cement volume based on open hole volume plus 30%, shoe joints and annulus. The job will consist of a lead and tail and cement will be brought to 4,000' MD. The estimated total volume is as follows: Lead: 3,164' X 0.1268 cuft/ft (8-1/2" x 7") X 1.3 = 522 cuft = 264 sxs (1.98 yield) Tail: 1,000' X 0.1268 cuft/ft (8-1/2" x 7") X 1.3 = 165 cuft = 142 sxs (1.16 yield) 40' shoe joint X 0.2148 cuft/ft = 8 cuft = 7 sxs (1.16 yield) TOTAL: 522 + 165 + 7= 694 cuft or 413 sxs Cementing Prog~am SCU 42-05Y 1 5l25/2007 ~ Surface Hole Recommendations Mud Type: 6%KCI, EZ Mud Pro erties: LJ Dens' y~s~i Plastic Visc~itv Yield Pant API FL ~H 0-1000' 9.0 60 - 85 7-16 30 - 40 N/C 8.5-9.0 1000-2000' 9.0-9.2 50-75 8-16 30-40 <5 8.5-9.0 System Formulation: 6%KCI, EZ Mud (if no used mud is available Product Concentration Water 0.905 bbl KCI 20 ppb (30K chlorides) KOH 0.2 ppb (9 pH) Barazan D 1.25-1.5 ppb (as required 35 YP) EZ Mud DP 0.75 ppb Aldacide G 0.1 ppb Baroid to a 9.0 ppg Baracor 700 1 ppb Barascav D 0.5 b add as the well s uds • Mix in order as listed • Add polymers slowly to minimize fisheyes. Production Hole Recommendations Mud Type: 6%KCI, EZ Mud Prooerties• Densi Viscosi Plastic V'-scositv Yield Point API FL gH 2000 - TD' 11-12.5' 40-50 12-27 16 - 28 <5 8.5-9.0 An offset well required a 12.5 ppg at TD. System Formulation: 6%KCI, EZ Mud Product Concentration Water 0.905 bbl KCl 19.8 ppb (30K chlorides) KOH 0.2 ppb (9 pH) Barazan D 1.25 ppb (as required 35 YP) De~rid 1-2 ppb EZ Mud DP 0.75 ppb Aldacide G 0.1 ppb Baroid as needed Baracor 700 1 ppb Barascav D 0.5 maintain er dilution rate . Mix in orde~ as listed • Add polymers slowly to minimize fisheyes ~ ~ Chevron Swanson River Field ~ SCU 42-05Y Drilling Waste Plan The water-base mud cuttings will be hauled from the SCU 42-05 Pad to the Swanson River Field Class II disposal well located on Pad SCU 243-4. A grind and inject facility will be mobilized and be located at the disposal well location ready to accept cuttings. The cuttings will be transported to the disposal well by vacuum trucks. In addition to the drill cuttings, excess water-base mud will be injected at the end of the project. The contingency plan in case the grind and inject facility would become inoperable for any reason is twofold. First, the cuttings may be loaded into tanks for storage until the grind and inject facility is operational. Second, the cuttings may be stored in the dedicated Swanson River Field Waste Cells. Drilling Waste Plan SCU 42-05Y ~ ~ Maximum Anticipated Surface Pressure Calculation Swanson River Field SCU 42-05Y Kenai Peninsula, Ataska Assumptions: 1. Based on offset drilling data, the maximum pore pressure gradient the drillina ahase will be 0.624 psi/ft from 9-5/8" casing shoe to planned total depth at 8,051' TVD RKB. This is due to the presents of high pressure water sands found below 6,800' ND. I have ran two cases, one with the 9-5/8" set at 2,500' ND and a second with the 9-5/8" set at 3,300' TVD. 2. The M.A.S.P. during drillinc~ operations will be govemed by the 9 5/8" shoe frac gradient, and is caiculated based on a full column of gas between the 9 5/8" shoe and the surface. 3. The M.A.S.P. during productionfin~ection phase will be the estimated SIBHP minus the gas hydrostatic pressure between TD & the surface. The maximum gas pressure within the storage reservoir is designed to be ~5,500 psi (0.687 psi/ft). M.A.S.P. During Injection Phase: Max. pore pressure at T.D. = 8,051 ' VD x 0.687 psi/ft = 5531 psi M.A.S.P. (tbg leak at surtace) = 5531 psi -(0.096 psi/ft ` 8,051 ft) _ = 4758 psi M.A.S.P. During Drilling Phase: Case I- 9-5/8" Shoe ~ 2,500' MD/2500' ND: Max. Est. Frac pressure at 9-5/8" shoe = 2,500 ft. x 0.728 psi/ft = - 1820 psi M.A.S.P. during drilling = 1820 psi -(.096 psi/ft x 2,500 ft.) _ = 1580 psi Case 11- 9-5/8" Shoe ~ 3,300' MD/3,300' ND Max. Est. Frac pressure at 9-5/8" shoe = 3,300 ft. x 0.728 psi/ft = = 2402 psi M.A.S.P. during drilling = 2402 psi -(.096 psi/ft x 3,300 ft.) _ - 2086 psi • ~ ~h@VI"Oti ~ LEAK OFF TEST PROCED~RE 1. Clean out the rathole below the shoe, and drill 20' of new hole. Circitlate and condition mud. 2. Pull the drill string into the shoe. Rig up to observe annulus pressures. 3. Close the pipe rams and pump down the drillpipe at a slow rate (1/4 - 1/3 BPM) if exposed formation is permeable. A non-permeable formation should be step tested to a predetermined pressure. 4. Measure the volume pumped and plot annulus pressure-vs-cumulative volume pumped. Compare annulus pressure to drill pipe pressure and confirm both are the same. Record and plot pressure versus volume pumped. The pumps should be shut down immediately upon indication of leak-off. Record the inital, shut down pressure and the pressure after 1, 2, and 3 minutes. 5. Release pressure and record the volume of fluid recovered in the trip tank. The point "B" shown in the attached graph at which the plot of drillpipe pressure stops increasing equally as the volume is pumped is called the P.I.T. limit, Leak Off, or pressure integrity test limit. The leak-off pressure is calculated as follows: Leak-off (EMW) = Mud weight in hole + P.I.T. (PSI~ (0.052) X(shoe depth in ND ft.) This equivalent mud weight should be made known to all drilling personnel to ensure it is not exceeded. See the drilling procedure for guidelines on expected LOT's or pressure integrity test limits for each casing shoe. SURFACE PRESS. TYPICAL PIT PLOT [psiJ NOTES: Point "A" will have some variance until the system begins to pressure up. Point "B" is the leak of~ and is abbreviated LOT. Point "C" is known as the injection pressure and is usually dependent on rate. Point "D" is Irnown as the fracture closure pressure and may not stabilize if permeable formations are exposed. VOLUME PUMPED SHUT-IN-TIME (BBLS) [MIN] Calculation & Casing Design Factors Swanson River FIe1d SCU 42A5Y Kenaf Peninsuta, Alaska WELL: SCU 42-OSY FIElO: Swanson River DATE: 24-May-07 DESIGN BY: Chantal Walsh Sect. 1 121/4" hole MUD WT. 9.2 PPG Sect. 2 8-1/2" hole MUD WT. 12.5 PPG TENSION MINIMUM COLLAPSE COLLAPSE WEIGHT TOP OF STRENGTH PRESS ~ REStST. MINIMUM ~ DESCRIPTION W!O BF SECTION TENSION BOTTOM w/o TENSION MASP YIEID CTIO AC SING BOTT TOP LENGTH V~,, GRADE THR A t B LB 1000 L SF TEN310N P~~I' ~{ SF COLL• PSI"' P$~ SF BURST 1 9 5!8" 2,SQ0 0 2500 47 L-BO BTC-mod 117,500 117,500 1088 8.24 1100 4760 4.33 1534 5750 5.75 ND 2,500 0 1a. 95/8" 3,300 0 3300 47 L-80 BTGmod 155,100 155,~00 1086 7.00 1452 4760 3.28 2026 5750 2.84 ND 3,300 0 2 7" 8,130 0 8130 28 L-80 BTC-mod 211,380 211,380 519 2.46 2899 5410 7.87 4769 7240 1.52 ND 8,051 0 ' Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (.44 psiHt) for the 9-5/8" and 0.687 psi/ft for the 7". The casing will be completely evacuated for the 9-5/8". For the 7", we will assume 5096 evacuation (0 psUft) and 50% with a 12.5 ppg mud (0.85 psilft). Notes: 1. All wellhead components are reted to 5000 psi working pressure. 2. Have ran two easea for the 9-Sf8" casing setting depths. ~ • • SCU 42-05Y BOP Stack up Bottom of Rotarv Table 13 5/8" 5,000 PSI ANN ADAPTOR S u 13 5/8" DIVERTER : . ADAPTOR SPOOL HELI RIG 106 - DIVERTER SYSTEM WITH 13 5/8" ANNULAR NABORS DRI~~If~G Scale: Date: N.T.S APR 11 2007 Drawn by: DWG# RAVI MANI NDR#106 Checked REV o0 by: qq CC 3-1/8" 5,000# NACE TRIM CHOKE & KILL MANIFOLD SYSTEM BB „~ r ~ ~a`•~'' PACIFIC VALVE SERVICES INC. VIEW VIEW VIEW ,r ~ v. ~ ~ O ~ ~ J W Z J ~ W ~ ~ W ~ ~ c0 O ~ ~ ~ J W 2 ~ ~ ~ z , ., . Shannon IA/. A~artin ; 3 ~ ~ Land Representative ~~~ ,~ MidContinent/Alaska ~ ~ ~"`~ ~ ~ 'VIA iJ.S. MAIL AND EMA~i. E~aii: a~t saltmarsh@adynim.state.ak.us vlay 14, 2007 l~Ir. Art Saltmarsh Alaska Uil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 APPLICATION FOR SPACING EXCEPTION Swanson River Unit (SRIJ) 42-OSY well A-028996, A-028997 Dear Mr. Saltmarsh: ~ Ctrevran P1ar2h A~ne~ca ~xplora4eon and Praduction 909 West 9`h A~enue P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7872 Fax 907 263 7898 Email smartin@chevron.com 7, ~N~~ j~ ~ . ~ ~~~ ~ `, ~ i~„ ~_...-„ i ;t j ~ ?` .:> ! ;3 e;'i ~ i -; ,: ;~'ia~~ 2 ~3 ~ i~~ w~ l~^~ ~~,; ~. j ;~;a +`A . ~'3 :~ ~ . . 1 t ).~,~ ;',~~ ~`~~~'~q~ ~ i~~~ .i . f . . Union Oii Company of California (Union 4il) hereby submits this Appiicatian for Spacing Exception ta drill the referenced "SRU 42-QSY" well in the Swansan River Fietd. Our antici- pated spud date is July l, 2047. In accordance with 20 AAC 25.OOS (a), a Pernait tv Drill and associated filing fees are enc[ased herewith. The SRU 42-OSY well is situated in ~overnmental Section 5, Township 7N, Range 9W S.M. and may require a spacing exception in accordance with 20 AAC 25.055 (a)(2} and (4). Should the resutts of the SRU 42-USY well be successful, said well will be within 1,Sp0' of a praperty line with a di~erent royalty percentage landowner. This regulation provides in per- tinent part, "a wellbore may be open to test or regulaz production within I,SOa feet of a prop- erty line only if the owner is the same and the landowner is the same on both sides of the line." in this instance the owner and the landowner are the same on each side of any affected property line however, the same landowners hold different royatty percentages in the cap- tioned oFfsetting leases. Although Union believes the landowner is the same per the definition af landowner (AS 31.05.17Q (7}}, in an overabundance of caution, we are submitting this ap- plication for spacing exception should you deem it necessary. Additionally, this wel( will be capable of delivering gas from the same pool as other wells. This regulation provides in per- tinent part, "not more than one well may be drilled to and completed in that pool vn any gov- a~n~mE+nta~ ea 4i r~; ~roll m~, .+..1~ !.n .7.~:114.~ Nl s 1 a~. ~'~C'V 1GG'L lV Gli~y ~Vtr'I~ ......~.. ~..e.,^v.. ?. Z..,,. ~.-?s uv~ v~. uaaaia.~a 3P C.viTi t~~~:ii ~.tvS2i t tu'lt"t .~ drilling to or capable of producing from the same pool." We don't believe this provision to be applicable for the pwrposes of redetivery of gas from a storage well, hawever, should you deem it necessary, we have included same as part of this application. ~~ ~r~~y ~b MidContinent/Ataska/Chevron NoKh America F~cpioration and Produttion www.chevcon.com Mr. Art Saltmarsh Alas~Ca Oil and Cias Co~se• mn Commission May ~ 4, 2007 Page 2 '1'he correlative rigltts of adl affected owners, landocvners and operators wi11 be protec~ed foy exception approval and by the terms of the Underground Gas Stora~e Agreement, Swanson River Gas Storage Facility Agreement #3 (Tyonek 77-3 Sand), Agreement Nc~. AA-Q85943, by and between the (Tnited States of America through its Bureau oF Land Vlanagement, and Union Oil Company af California. Additionall . torage Injection nrder No. 6 uthorizes ~as storage in the Tyonek 77-3 Sand. ~`- At the date of this mailing, in accardance with 20 AAC 25.055 (d)(1), notice of our intent to drill has been sent by certitied mail to all owners, landawners, and operatars of all vutly~ng properties within 3,000 feet of the SRU 42-OSY well. "Chis application was sent to each land- owner and constitutes "landowner notice". Certi~ied mailing receip#s are attached to this ap- plication. Pursuant to 20 At1C 25.055 (d)(2}, enclosed is a plat, identified as F_,xhibit "A", which shows the location of the well far which the exception is sought and all adjoining propcrties. Also enclosed, Exhibit "A-1" identifies the owners, Iandowners and operators associated with each [ease. Pursuant to 20 AAC 25.055 (d)(3), an affidavit is enclosed stating the undersigned is ae- quainted with the facts and verifying that all facts aze true. It is requested that the Comtnission approve this exception application to the statewide spae- ing regulation for the drilling of the proposed SRU 42-QSY well. Additionally, because we anticipate drilling additional gas storage wells in the Swanson River Field in the neaz future, we request that the AOGCC issue a conservation order allowing Union Oil to file for adminis- trative approval in connection with future gas storage wells in the Swanson River Field, which will ease the administrative burden of filing for individual spacing exceptions. If you require additional information regarding this spacing exception application, please con- tact Ms. Chantal Walsh, drilling engin~;er at 263-7627, or the undersigned at 907-263-7872. Very truly yours, 7 ____ , :'~_ , •i'-}~"~~G~ ~/~ ~~`'~'~~`~- ~_ ~ / (~ Shannon W. Martin Enclosures cc: Kim Cunningha;r~, CIRI (via certified mail) Greg Noble, BLM (via certified mail) MedContinent/Alaska/Chevron North America Exploration and Produd[on www.chevron.com Mr. ~rt Sa~t-r~arsn ~laska Oit and ~as ~onser•ic~n Commission May 14, 2007 Page 3 VERIFICATION OF APPLICATIO~F FOR SPACING EXCEPTION COOK INI,F.T, ALASKt1 A-028996, A-028997 SRU 42-OSY well I, S~iANNON W. MARTIN, Land Representative, IJnion ~il Campany of California, do hereby verify the following: I am acquainted with the applicacion submitted far the drilling of the SRU 42- OSY gas storage well in the Swanson River F ield. I have reviewed the application submitted for the exception to 20 AAC 25.055 (a)(2) and (4) and all fac:ts therein are true. I have reviewed the plat attached ta said application, and it corrcetly portrays pertinent and required data. DA`I`ED at Anchorage, ~11aska this 14th day of \rlay, 2007. _ --~ -~ ~ ~' % ,~ - ~' Z'' ` ~ _-~~-~Z ~ , " on W. Martin I,and Representative STATE 4F ALASKA ) ) ss "1'~IIRD JUDICIAL DISTRICT ) SUi3SCRIBED TO AND SWQRN before me this 14th day of May, 2007. ST~`~ C~~ A~,~iS~i NOY~IRY ~U~lJC Juditi• ~,. St~n~~ G~ ~ ~~ '~ ~y~ ~s r~txuray ia, z~fp N TARY PUBLIC IN AND FOR THE STATE OF AI,ASKA My Commission expires: ~ -/~-,s'tJ iNidCuntinent/Alaska/Chevron North America Exploration and ProducNo~ www.chevron.com Mr. Art Saltma.rsh ~ Alasfca Oil and Gas ~onservatIIOn Cvmmission May I4, 2~07 I'~ge 4 ~X~I~I'I' "A-1~~ LEASE LANDOWNERS OWNER OPFIKA'T4R Bureau of Land Management, 6881 Abbott I.oop Road Ancharage, AK 99507 Union Oit Company of Union Oil Company A-028996 Att: Gre Nob[e California ofCalifornia Cook Inlet Region tnc. 2525 C Street, Suite 500 Anchurage, AK 99509 Att: Kim Cunnin am Burcau of Land Management, 688 t Abbott Loop Raad Anchocage, AK 99507 Union Oil Company af Union Oil Company A-028997 Att: Gre Noble California of ~alifornia Cook Inlet Region Inc. 2525 C Street, Suite 500 AnchQrage, AK 99509 Att: Kim Cunnin am MtdContinent/Ataska/Chevron North America Exptoration and Production www.chevron.com ~I i~ ~ • E~tHIB1T ,4 _; ~n ~ ~ ~~~~.~~~~~~ ~ k ~ ~: ~ ~ ~ ~~~.~..; -xri ~ ~ ~ r ~~~~~y~~..~~:~~..,~_.,~ . . >~ ~~ ~ ~~~~ ~~~.~ - ~ i;~'., .. . §~ ,.4.; k ; . . -.-.~ . . ~ ~ ~~`~~ ,~~c~ , , - ~~~~ O ~ ~ ,~ ~: ;.~ ~~ ~ ~. _~~k~_ ,._ ,_ ~= ~`~ '_ ~~~~. ~ ~ ~ ~~ ~_~' ' . . . .~ .- _ =~ 5;'= _ i ~e~.~ . . ~ ~ d . __ .:7'. ~ '~"~ ~ . . . ~ ` .~ ~ .~ ~.r~'#~ ~ - ~_~_~.. . ~~.~ ~ ~. ~~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ow~o~ .:~¢ r - ~cn~srt S'WA~7SCJ~d 3~VER FIELd3 ~ ~ `3`-~? a Proposed Location 42-05Y ° - '• -~ ' - ~ °-~ .--~ ~~x~t ~t:.4:~~-0-~.~ ,(,/ZGI _ . _ '~ .. ,2~SZ~ G SI"_ S•~~'9 ~~?D ~ Q ~ S rn ,~,~J s C,~,o i(2,~'y~„ - r.t..~..._ ~7~5 ~!_-- ------. _ .. -_ _ oF' lY~ ---- _... __ _-__- -- - 6. ./-1 +-1, ~ -t-.~ ~~°n C:.~~~,~ ~ ~ iw .~,._. ~ ~ ~ ~ ~ ~~ , _ ~ ~YJ 606o p~g~~ i ~~,;~y ~ -----(3 ~~_c.u..~,~ _ ~---1-x.~ ~1cii^~,r~t~1+.~- -.,. --- ---- ~_.._......_ 7. t~ S~1' I ~~ ~~ ~ ~OG I~ ~ ~ ~ ~ - ~ ! ~~ S l ~1,~,_~l1rVO~ lt, ~r ~ _ ,~- ~t ~ -~ so- i ---_--- _._ . __ _ . _.._ ... ~ ~i,-,~._-~-~=~ ---~?Q~~- ; ~~,,, a.(2~, _ _- - ~ , 8~ -1'~ ?~~1 S~~ ac~~a c~o~,( i ~{,~Z _ _ . ~ i ---- -- - - _ . __ u..._ _.: ---- 7otal Number ol ~ioces I Total Numbor ot Pieces i Postmaster, Listed by Ser.der Received at Post Office S - ~ i ~ PS Form 3877, February 2002 (Page 4 0/2) ., _____,--- ~. , ~-- ~ - ,_ - .~. . --~--..._. ~ , ~ i ~ ~ ' I ' . ........ ..,.~_ ! ~.... _' . _. _ .e . _. . ~ ( ' } I i I ~ a- -~ - - ,_ ~ _ - ---_ - - ~ -- ~ i ~ ' ~ i ; _~_ ~____ _ ._ See Privacy Act Statement on Reverse Comptete by Typewriter, lnk, or Ball Pofnt Pen ` ,: ~~ , ~~ ` r ., -, . ~ _ ~ _ , t , _ ._A. , . i c ~~;i.''. ~' °-, ~.'~_.,,~ .~ ._? !~, ~f (~ _r` ~~ ~~ ~ .~~ , _ ,..- ... ,_,. - ~,: ~ r; _ ' . .t , . yV''''1 ! , n. 1/ ~ ~!' ~ ( ' ,; `"~..+ ~ ~ ~?~'`-_._ ~ ('~. ,.+1 ,.~._~ ~trt~ . _.r.i`~ ~.~.,-~> ~,:)-C._, #!._._~.~!~_~~` ~....~..~ ~ _~ . ~`y .;~_.. ti l~ 3 ( {- :~~. ,-) -~` t ~ ~„.~ ~` ' 1 r:~;..~..._S? s~-~:~'~ C'_ ti c.%~:~, \t:' t ,t (>C'":i_•~r ~ ~ _~ ~~;~,~,/, • ~ ( ` f C_,e ..~-~"~'~~v~~_ d~~~. +~..'~ .-~~.(....- ~~ , , , , , . li~,:~-;ri t ?..%~.~;_.. , *• t _ . ~"~~= ~ ~_..~~ ~„ ~.,.~ . ~ ' ! ~ • EXHIBIT A Underground Gas Storage Agreement Swanson Fiiver Gas Storage Facility Agreement #3 (Tyonek 77-3 Sand) Agreement No. AA-085943 GAS STORAGE RESERVOIR AREA ~ `: i ! 3 ~ ~ ~ ~ ------ --~ ;a 310CI< 1 ~ !; _ , ii ,~ y - '~~ , , , ~ ~ _. :>= .. `~____ ( ..~~~~~~~~~~~-~..._ .,.T_ _ ~ ^~ ' ~ ~' ~ ', 31oc!< 2 ' ~ 2~ ~ ~ ' _ ~ r-~~--~-~~,-- ,- , ~ - -- -----~ _~~ _.- ~ - , ;, , ~ i ~ i ; , ~ ~ ~~ ~ i ~ ~,. ~ r~ ,. ~ ~ ~ _ ~,a_.! , ~ ~ ~, ' : . ' ~ .~ :.~ . .~ ~ •: ' ,, .., :~ ~: ~ ~'' < ~ '~~~ ~, ~~ I y % ~ ~ ~;i t r ,, __ ~ 7 "; ~ ~ ~) ' SRGSFN3 ~' %' ~" `~ ~ ~•_~}''+. 77-3 Sand Reservoir Leases p ~ Swanson River Field Tracts ~ September 1, 2005 Scale: 1:36,000 EXHIBIT B Swanson River Gas Storage Facility Agreement #3 (Tyonek 77- 3 Sand) Agreement No. AA - 085943 Committed Basic Description of Participating Royalty Owner Overriding Working Participating Lands Acreage and Serial and Lessee Royalty Owner Interest Owner 8 Tract No. Nnsurveved) Percentaqe Number Percentaqe of Record and Percentaqe Participation BLOCK 2 SOLDOTNA CREEK UNIT 15 T7N. R9W. S.M. AK 90.00 A-028996 USA 11.1607143% Fred W. See "E Zone #4 Unocal 100% 23.68% CIRI 1.3392857% Axford PA" Sec 5. SE1/4 NE1/4, 40 acres; E1/2 SW1/4 NE1I4, 20 acres; N/2 NE1l4 SE1/4, 20 acres; NE1/4 NW1/4 SE1/4, 10 acres; 16 T7N, R9W, S.M. AK 290.00 A-028997 USA 9.3750% Fred W. See "E Zone #4 Unocal 100% 76.32% CIRI 3.1250% Axford PA" Sec 4. W1/2 SE1/4 NE1/4, 20 acres; SW1/4 NE1/4, 40 acres; S1/2 NW1/4, 80 acres; NE/4 SW1/4, 40 acres; N1/2 NW1/4 SW1/4, 20 acres; SE1/4 NW1/4 SW1/4, 10 acres; NE1/4 SE1/4 SW1/4, 10 acres; NW1/4 NE1/4 SE1/4, 10 acres; NW1/4 SE1/4, 40 acres; N1/2 SW1/4 SE1l4, 20 acres, Block 2 Total 380.00 100.00% ~ ~ Production Aliocation- If there is production from the 77-3 Sand, the allocation will be based on the 8910086520-C (S20), "E" Zone Gas Pool #4 Initial Participating Area, Exhibit B-1. ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7t'' Avenue, Suite 100 Anchorage, Alaska 99501 Re THE APPLICATION OF UNION ) OIL COMPANY OF CALIFORNIA ) ("Unocal") for an order authorizing ) the underground storage of ~ hydrocarbons in the Tyonek 77-3 ~ Sand, Swanson River Field, Cook Inlet ~ Area, Alaska. Storage Injection Order No. 6 Swanson River Field Tyonek Unde~ned Gas Pool October 31, 2005 IT APPEARING THAT: 1. By application dated August 24, 2005, Union Oil Company of California ("Unocal") as operator of the Swanson River Field, requested an area storage injection order from the Alaska Oil and Gas Conservation Commission ("Commission") authorizing the underground storage of natural gas in the Tyonek 77-3 Sand within the Swanson River Field. 2. Notice of opportunity far public hearing was published in the Anchorage Daily News on September 6, 2005 in accordance with 20 AAC 25.252(i) and 20 AAC 25.540. 3. Unocal submitted additional information on September 7, 2005 and September 22, 2005. 4. A revised notice of opporiunity for public hearing was published in the Anchorage Daily News on September 7, 2005 in accordance with 20 AAC 25.540. 5. The Commission received no protests to or written comments on Unocal's application. 6. The Commission held a public hearing October 13, 2005 at the Commission's offices at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. FINDINGS: 1. O~erator: Unocal is the operator of the Swanson River Field. There are no other operators within a one-quarter mile radius of the boundaries of the proposed storage area. 2. Injection Strata: Unocal proposes to inject gas into the Tyonek 77-3 sand within the Swanson River Field. The Tyonek 77-3 sand accumulation occurs at depths of 7972 to 8001 feet measured depth within Well SCU 42A-O5. ~ ~ Storage Injection Order 6 Page 2 October 31, 2005 3. Proposed Stora e Area: The hydrocarbon-bearing interval of the Tyonek 77-3 sand is located within Sections 4 and 5, Township 7 N, Range 9 W, SM. 4. Operators/Surface Owners Notification: Unocal has provided an affidavit showing that the Operators and Surface Owners within one-quarter mile radius of the proposed storage well have been notified. 5. Description of Operation: Unocal proposes injection of hydrocarbon gas into the Tyonek 77-3 sand for gas storage purposes. Produced natural gas from the Swanson River Field and from other fields in the Cook Inlet area will be injected and stored in the proposed storage interval during periods of high supply and redelivered during periods of high demand. The estimated maximum amount of gas to be injected is 42 MMSCFD. Existing compression will be used for gas injection and production operations and has a capacity of 4400 psi corresponding to a 0.676 psi/ft gradient. The average wellhead injection pressure is projected to be 3500 psi. Original reservoir pressure in the 77-3 sand in SCU 42A-OS is estimated at 4774 psi and equates to an original pressure gradient of 0.61 psi/ft. Unocal's ariginal application identified Tyonek 77-3 sand producer SCU 42A-O5, as the single proposed gas storage injector for the project. Unocal has also requested permission to be able to recomplete other wells within the approved storage area such as SCU-42-OSB for starage service. 6. PoolInformation: Information provided by Unocal indicates that the requested affected area for this order contains 100% of the net sand mapped to date in the Tyonek 77-3 Sandstone. The Tyonek 77-3 Sandstone is interpreted as a meandering stream deposit with river channel sandstones laterally equivalent to predominately fine grained floodplain mudstone and coals. Lateral facies changes from sandstone to mudstones in the eastern portion of the affected area form a stratigraphic trap element in those areas. An updip sealing fault provides the trapping element along the southern portion of the affected area. A fault seal along the northern boundary of the reservoir and uniform dip to west provide structural trap elements along the northern and western portions of the area. The dependence of this trap configuration on a potentially dynamic up-dip fault seal will require an engineering based justification for injection pressures exceeding the original conditions within the proposed storage reservoir. Core data from the Tyonek 77-3 Sandstone indicate average net reservoir porosity of 28°/o and permeability ranging to several hundred millidarcies. Gross thicknesses for the 77-3 Sandstone range from 25 to approximately 40 feet based on well control. Average water saturation is estimated at 50%. The sandstone is bounded above and below by confining zones consisting of fine grained fluvial overbank deposits of mudstones and coals exceeding fifty feet in true stratigraphic thickness. SCU 42A-O5, completed in June 2004, is the only well that has produced from the Tyonek 77-3 Sand. Peak production rate was 6.2 MMSCFD. Initial reservoir pressure within the sand was 4774 psi. Original gas in place is estimated to have been i Storage Injection Order 6 October 31, 2005 Page 3 3.18 BSCF using material balance analysis of historical production and reservoir pressure measurements. A volumetric estimate of about 2.8 BSCF compares well with the material balance results. As of July 1, 2005, recovery was 1.8 bcf corresponding to a recovery of 57.5% of the original gas in place and an average reservoir pressure of about 1900 psi. Material balance analysis supports the contention that the interval proposed for gas storage covers a limited area and is pressure isolated from other strata. 7. Well Lo~s: The logs of existing wells in the area are on file with the Commission. 8. Mechanical Inte~ntv and Well Desi~n of Injection Wells: Injector wells will be permitted and completed in accordance with 20 AAC 25.030. Cement bond logs will be run on all injection wells to demonstrate isolation of injected fluids to the Tyonek 77-3 Sandstone. The operator will demonstrate mechanical integrity of the injection wells according to the provisions of 20 AAC 25.252(d) befare initiating gas injection and storage. 9. Ty~e of Fluid / Source: Only dry natural gas from the Swanson River Field and other Cook Inlet area fields will be injected and stored. The gas specific gravity is between 0.56 and 0.58. 10. Fluid Compatibility with Formation: Since the composition of the injected gas is very similar to the native gas, there will be no compatibility problems. 11. Injection Rates and Pressures, Fracture Information: Injection rates will vary dependent upon gas supply/demand and the reservoir pressure during storage. The maximum expected injection rate is 42 MMSCFD. Estimated average and maximum surface injection pressures are 3500 psi and 4400 psi, respectively. No direct fracture gradient measurements in the Tyonek 77-3 Sand have been made. Fracture gradient is estimated at 0.81 psi/ft based upon data gathered during cementing operations in a zone just below the Tyonek 77-3 Sand. In other tests of shallower formations, the observed fracture gradients ranged from 0.75 to l.l psi/ft. The original Tyonek 77-3 reservoir pressure gradient was 0.61 psi/ft. At planned maximum rates and pressures, the gradient will be less than 0.674 psi/ft at the injector, well below the fracture gradient of stratigraphically adjacent mudstone con~ning zones. No information has been submitted characterizing the pressure integrity of the updip fault seal along the southern portion of the affected area. Unocal sought the flexibility to inject at pressures up to 10% above the original reservoir pressure. Unocal presented no direct evidence of the competency of the fault seals if the reservoir were pressured to above the original reservoir pressure. • 12. Underground Sources of Drinkin~ Water: ~J Storage Injection Order 6 October 31, 2005 . Page 4 The proposed gas injection will occur at depths greater than 7800 feet TVD and will be adequately confined at the approved injection pressures. As per 40 CFR 147.102(b), the aquifers greater than 1700 feet below the surface in the Swanson River Field are exempted in accordance with 40 CFR 144.7(b) and 40 CFR 146.4. 13. Mechanical Condition ofAdjacent Wells: Unocal supplied a report on the mechanical condition of each well that has penetrated the Tyonek 77-3 accumulation within the proposed storage area. Cementing records suggest full cement placement within all wells and there are no known mechanical integrity issues. With the exception of two wells, SCU 323-04 and SCU 41-05, cement evaluation logs verified good cement. No bond log was run on SCU 323-04. While the bond log on SCU 41-OS indicated insufficient isolation of the 77-3 Sand, cementing records indicate successful cementing operations with fu11 cement placement. Reservoir material balance results support the contention that the interval proposed for gas storage covers a limited area and is isolated from other strata. 14. Additional Safety Precautions/Risk Reduction: Unocal performed a risk analysis on the proposed gas storage operations. Compression will be supplied by the existing central Swanson River compressor facilities, which have been used for gas re-injection into the Hemlock oil zone. The maximum operating pressure of the compressor is 5000 psi. Emergency response plans are in place for the Swanson River Field that cover these operations. A potential storage we1142B-OS is currently completed within the Hemlock formation. Unocal indicated that the production casing has good cement well above the Tyonek 77-3 Sandstone. The current completion will be abandoned, current tubing will be pulled, a new 5'/2" liner will be cemented from below the storage zone to surface, and a new 2 7/8" tubing string with premium threads will be run. The pressure ratings of casing and cement are well above the maximum allowable injection pressure. The tree is rated at ANSI 5000#. Surface safety valve ("SSV") and an additional check valve will ensure that surface injection pressures cannot exceed 4400 psi. The injection well will be remotely monitored. Tubing and annular pressures of all wells within the storage area are monitored daily. CONCLUSIONS: Subject to the limitation of Rule 4(a) of this order, the project as described and proposed satisfies the requirements of 20 AAC 25.252. 2. Mechanical integrity of all storage injection wells must be demonstrated according to the requirements of 20 AAC 25.252(d) prior to initiating gas injection and storage operations. 3. The proposed injection of natural gas into the Tyonek 77-3 Sand for the purpose of storage will not propagate fractures through the confining zones or cause movement ~ ~ Storage Injection Order 6 Page 5 October 31, 2005 of hydrocarbons into sources of freshwater. 4. The proposed injection of natural gas into the Tyonek 77-3 Sand for the purpose of storage will not cause waste, jeopardize correlative rights, endanger freshwater, or impair ultimate recovery. 5. The proposed injection operations will be conducted in permeable strata, which can reasonably be expected to accept injected fluids at pressures less than the fracture pressure of the confining strata. 6. Data as to whether the reservoir compartment will maintain pressure integrity if the average reservoir pressure exceeds the original reservoir pressure are insufficient to justify allowing injection to increase reservoir pressure above the original pressure. 7. Surveillance of operating parameters on the storage and offset wells will aid in preventing stored gas from moving out of the formation where it is intended to be stored. NOW, THEREFORE, IT IS ORDERED that the following rules, in addition to statewide requirements under 20 AAC 25, apply to the underground storage of hydrocarbons by injection operations in the Tyonek 77-3 Sand accumulation in the affected area described below: Seward Meridian Townshiu 7N, Range 9W Sec 4: Wl/2 SEl/4 NE1/4; SW1/4 NE1/4; S1/2 NWl/4; NEl/4 SW1/4; N1/2 NW1/4 SWl/4; SE1/4 NWl/4 SW1/4; NE1/4 SEl/4 SW1/4 NWl/4 NE1/4 SEl/4; NWl/4 SEl/4; Nl/2 SW1/4 SE1/4; Sec 5: SE1/4 NE1/4; E1/2 SWl/4 NE1/4; N1/2 NE1/4 SE1/4; NEl/4 NW1/4 SE1/4 • ~ Storage Injection Order 6 Page 6 October 31, 2005 RULE l: STORAGE INJECTION The Commission approves the injection for storage of natural gas into the 77-3 Sandstone of the Tyonek Formation, common to and correlating with the interval of 7972 to 8001 feet measured depth within Well SCU 42A-O5. The Operator shall report disposition of production and injection as required by 20 AAC 25.228, 20 AAC 25.230, and 20 AAC 25.235. RULE 2: DEMONSTRATION OF MECHANICAL INTEGRITY A Commission-witnessed mechanical integrity test must be performed after injection is commenced for the first time in the well, to be scheduled when injection conditions (temperature, pressure, rate, etc.) have stabilized. Results of inechanical integrity tests must be readily available for Commission inspection. RULE 3: WELL INTEGRITY FAILURE AND CONFINEMENT In addition to complying with 20 AAC 25.252(e), the operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. The operator shall submit to the Commission a monthly report of daily tubing and casing annuli pressures and injection rates, for all wells within the affected area. RULE 4: MAXIMUM INJECTION PRESSURE (a) Injection operations may not increase the average reservoir pressure beyond original conditions of 4774 psi. (b) To allow for friction losses through injector perforations, the injection pressure at the formation sandface may reach a maximum allowable gradient of 0.676 psi/ft TVDss, so long as the limit in item (a) of this rule is not exceeded. RULE 5: ANNUAL PERFORMANCE REPORT An annual report evaluating the performance of the storage injection operation must be provided to the Commission no later than 60 days after the beginning of each calendar year. The report shall include material balance calculations of the gas production and injection volumes to provide assurance of continued reservoir confinement of the gas storage volumes. RULE 6: EXPIRATION OF APPROVAL As provided in 20 AAC 25.252(j), if storage operations are not begun within 24 months after the date of this Order, this injection approval shall expire unless an application for extension has been approved by the Commission. ~ ~ Storage Injection Order 6 Page 7 October 31, 2005 RULE 7: ADMINISTRATIVE ACTIONS Unless notice and public hearing are otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. DONE at Anchorage, Alaska and dated October 31, 2005. John K. Norman, Chairman Alaska Oil and Gas Conservation Commission Cathy P. Foerster, Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23" day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30 day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10'~ day afrer the application for rehearing was filed). ~ ~ i • ~'RANS1dII~'T'A~. LE~'TER C'H.~CKL~ST _ Development ~ Service Ex lorato Noa-Cooventional We1t P ~'~ Stratigraphic Z'est Circle 4ppropriate Letter / Paragraphs to be taclud~d ia Transmittal Letter ' CE~CK ~ w'i-IAT ; APPL[ES ~vE~L ~~~yrE _ ~'~~/ ~ -D~Sy P~o# ~o~o~~o AUU-Vi~/5 (OPT[ON S) I MULTI LATER.AL ~ (IF ta,t two digits ~ ~P[ number ,' between 60-69) PILOT KOLE 1"EXT FOR APPROVAL LETTER ! T'he permit i; for a new we[16ore segment of exi~ting ~ we[! ~n I Permit Yo. are , API No. ~0- _ _ ! Production shou[d continue to be repoRed as a of the ~ ~ origina[ .4P[ number sta,ted above, i tn accordance with 2p A.4C 2~.OU~ ~ ; acquired for the pitot hole must be (ctearly diffecentiated~n both ~ ; wet! name ( i(~Q- _ PE~ and API number ~ _) from records, data and logs ~ , acquired for we(1 The permit is approved subject to futt compliance with 2p pqC I ; 2~•~». Approvat to perforate artd produce / iniect is contingent ± I upon issuance of a conservatioa order approvin~ a spacing ~ ; exception. ~/~yi~A/ QiG G~' ~'/~'o,~s ~ _~ liabi[ity of any protest to the spacing exception t~hat -may occrus ~e j ~ SPACENG / ! EXCEPTION ; DRY DITCH i SA!~tPLE i ; J A(! dry ditch sample sets subrnitted to the-£o~mrs,,~o~ must be in ; i no greater than 30' sampte intecvals from be~ow~ d1e permafrost o~ ' I from where samp(es are fint caught and i0' samp(e intervats ; j through tatget zones. ~ ; ~ I~ton-Coaventionaf j Well I j Please note the fo[lowing specia! condition oP this , i permit: , ~ production or pcoduction testing of coat bed metharte is not al(owed ~ ; for (reame of weil) unti! after (Cornoanv Iv_'~h~ aesigned and i ~ implemented a water weti testing program to provide basetine data ; on water quality and quantity. (Comnanv lYame) must contact the i i Commission to obtain advance approva! of such water wet( testing ; ' ~0~~- I Rev: I 2~i06 C ^jody~traasmittat_checkl ist Field & Pool SWANSON RIVER, STERLING UND GS - 77255 Well Name: SOLDOTNA CK UNIT 42-05Y Program SER Well bore seg ^ PTD#: 2070820 Company UNION OIL CO OF CALIFORNIA Initial Classlfype SER I PEND GeoArea 820 Unit 51994 OnlOff Shore On Annular Disposal ^ --- Administration ~1 Pe[mikfeeattache_d_______.._____________________„_, ____.__._ Yes_____ ._____ 2 Leasenumberappropriate_ _____________. Yes_____ ____ __ 3 Uniquewell_nameandnumber_____________________________ _______. Yes_____ _ ----- --- - ------ - - ---- - -- ~ 4 Welllocatedin_adefinetl_pool-------_------_------------- --------- Yes----- ----------------------,--__- 5 Well located p[oper distance from drilling unit_bound.a.ry_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ Spacing Exception required; Waiting pn Public Comment period and Hearing (July 12, 2007). _ _ . , _ _ _ . _ . . , _ 6 Welllocatedproperdistancefromotherwells_____________________ _ _______ No______ __AsAboye.____._______,_ ~7 Sufficientacreageayailablein_d_rillingunit______________._______ _________ Yes____ _. - 8 Ifdeviated,is_wellboreplat_inclu_ded__________._____ ________ _________ Yes_____ __ - ~9 Ope[atoronlyaffectedparty------------------------------- --------- N°------ -- 10 Ope[a#orhas.appropriate_bondinfor~e- ---- -- -- - - - - Yes--- -- -- - - -- --------- ----- --- --- - -- - ---- -- -~ 11 Pe[mitcanbeissued_w_ithoutconservationorder _ ____ _ No ____ _ _ _______ ___ _____ ______ ___________________,___. ~ Appr Date 12 Permitcanbeissuedwithoutadministrative_approyal________________ ___ _____ Yes___. ___._,___________. -- - - - ACS 6/2712007 13 Can permit be approved before 15-day wait No 14 Well locaked within area and_strata authorized by_ injection Order #(put 10# in comments) (For Yes _ . . 15 All wells_within 114_mile_area_of reyiew identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ - - - - --- 16 Pre-produced injector. dur_ation_of pre p[oduction less than 3 months_ (For_se[vice well only) ___N_A_ _____ ____ - 17 _N_onconven,gasconformsloAS31,05,030(j.i_.A),(~.2.A-D) _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ . _ _ . . Engineering 18 _C_onductorst[ing.Rrovided--------------------.--------- --------_ Yes----- ----- -- ------ ----------------------------------.-------- 19 Su_rface casingprotects all.known USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Ye~ . _ _ _ _ _ _ Surf_ac~ ~sing at_250Q' lvd, All aquifers exempted below 170Q tud, 40 CFR 147.102_ (b)j1_)(q, _ _ _ _ _ _ 20 CMT vol adeguate_to ci[culate_on conductor & surf_csg _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 21 _C_MT_voladequate_totie-inlongstri_ngtosu_rfcsg_____ ____________ __________ No_.,___ ___.____.,_____._.___ 22 CMT_willcoverallknow_n,productivehorizons_____________________ _________ Yes_____ __ - 23 Casingdes9nsadepuateforC,.T,6&.petmaf[ost----- ---------__ --------Yes-__ --.-_-----------------------------.-,-.----------_----------------- 24 Adequate tankage_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ Rig is_equipped with steel_pits. _ No [eserve_pit~lanned. All waste to_approyed disposal well(s). _ _ . _ _ _ _ _ _ _ _ _ 25 If.a_re-d[ill, has a 10-403 for abandonment be_en approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ 26 Adequate wellbore separation_proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Proximity analysis performed, T[ayeling cylindel path calculated, Gyros possible, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Ifdive~terrequired,doesitmeetregulations___.____________._ __.____Yes_____ ____________________,__ Appr Date 28 Dnlling fluid_ proqram schematic_& equip listadequ~te_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . _ _ _ _ _ Maximum expectQd fo[matiqn prQSSUr_e 12A EMW._ Planned MW up t912.5 ppg. _ . _ _ . _ _ . . _ . , _ _ _ _ _ _ _ _ TEM 7/6/2007 29 _B_OPEs,_dotheymeetregulation----------_ Yes----- ----- ~~~ 30 BOPE_press rating approp[iate; test to_(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ . _ _ _-----_-_----.-_---------------------------- _ _ MASP with surface_shge fracture up to 2100_psi: 300Q psi BOP test_proposed, _ _ _ _ _ . _ . _ _ _ _ _ , _ _ _ 31 Choke_manifoldcompliesw/APl_RP-53(May84)_________ _________ _________Yes__._. ___,__._._____.._._____________ 32 Workwill9ccu[withoutoperationshutdown______________________ _________ Yes__ __ _______ 33 Is qresence of H2S gas prpbabl_e _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ . _ _ _ _ . _ H2$ has not been reported in the gas_or sto[age [eservoir. Righas sensors and alarms, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 34 Mechanical_condition of wells within AOR yer~ed (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ AOR wQlls_iden#ified._ Wells monitored per SIO ~6. _ No issues identifed. , _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ Geology 35 Pe[mit_ can be issued w!o hydrogen sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ -- - - --- _ _ _ _ _ _ _ - 36 Data_presented on_ pote_ntial overpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ , _ _ _ Appr Date 37 Seismic_analysis of shallow gas_zones_ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ ACS 6/1112007 38 Seabedconditionsurvey_(ifoff-shore)_____________ ___________ ___,__ NA______ _ - - - - - - - _______ 39 Cont_act nameJphone for weekly_ proqress reports [exploratory only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ . _ _ _ . Timothy B[andenburg - 907-263-7627_ _ _ _ _ . _ _ _ _ _ _ _ , _ _ _ _ . _ _ _ _ _ _ Geolagic Engineering Public Commissioner: Date: Commissioner: Date Co ' si er Date ~r~ ~ ~ 7 ~~~ ~-s-~~ 1 1 ~-~..~~ ~