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180-114
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 31-33WD SWANSON RIV UNIT 31-33WD Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/17/2023 31-33WD 50-133-20336-00-00 180-114-0 W SPT 1906 1801140 1500 786 786 789 778 4YRTST P Adam Earl 3/16/2023 MIT-IA---- NO O/A 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:SWANSON RIV UNIT 31-33WD Inspection Date: Tubing OA Packer Depth 225 1745 1745 1745IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230322110744 BBL Pumped:0.2 BBL Returned:0.2 Monday, April 17, 2023 Page 1 of 1 9 9 9 9 9 9 99 999 9 9 9 'LVSRVDOLQMHFWRU James B. Regg Digitally signed by James B. Regg Date: 2023.04.17 15:43:12 -08'00' MEMORANDUM TO: Jim Regg '�&� 41� 65 P.I. Supervisor FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 8, 2019 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC - 31-33WD SWANSON RIV UNIT 31-33WD Sre: Inspector Reviewed B-�y-r::rr?� P.I. Supry Jr71�— Comm Well Name SWANSON RIV UNIT 31-33WD API Well Number 50-133-20336-00-00 Inspector Name: Jeff Jones Permit Number: 180-114-0 Inspection Date: 3/252019 , Insp Num: mid.1190403165427 Rel Insp Num: Notes; Monobore injector; no OA. I well inspected, no exceptions noted. ✓ Pretest Initial Packer Depth 45 Min 60 Min Well 31- D 790 Type lnj v TVD 1906 ' j Tubil PTD 1801140 Type Test SPT Test psi 15oo IA BBL Pumped: 0.1 BBL Returned: 0.1 OA Interval I 4YRTSr P/F I P 11 Notes; Monobore injector; no OA. I well inspected, no exceptions noted. ✓ Pretest Initial 15 Min 30 Min 45 Min 60 Min 725 12S 790 750 58 1609 1581 '579 Monday, April 8, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,March 31,2015 Jim Regg P.I.Supervisor Fet1 4181/5 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 31-33WD FROM: Bob Noble SWANSON RIV UNIT 31-33WD Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry �? NON-CONFIDENTIAL Comm Well Name SWANSON RIV UNIT 31-33WDAPI Well Number 50-133-20336-00-00 Inspector Name: Bob Noble Permit Number: 180-114-0 Inspection Date: 3/23/2015 Insp Num: mitRCN150324091825 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3l33\ Type Inj "TVD 1906 Tubing] 77° 795 sis 820 820 PTD" 1801140 "Type Testi SPTTestpsi 1500 "I IA 67 1649 • 1652 - 1648 1648 Interval 4YRTST PIF P OA - -- -- --- -� -------- -=-- � -- ' - Notes: Tuesday,March 31,2015 Page 1 of I UNSCANNED, OVERSI7ED MATERLALS AVAILABLE: l~U ~%~_ TILE # r`.~~ v~~ ~ ~~~r To request any/all of the above information, please contact: Alaska Oil & Cas Conservation Commission X333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 Tax (907) 276-7542 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, March 25, 2011 TO: Jim Regg P.I. Supervisor 2 " -3-11( SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 31 -33 WD FROM: Jeff Jones SWANSON RIV UNIT 3I -33WD Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: SWANSON RIV UNIT 31 - 33WD' API Well Number: 50 133 - 20336 - 00 - 00 Inspector Name: Jeff Jones Insp Num: mitJJ110323075136 Permit Number: 180 -114 -0 Inspection Date: 3/23/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 31- 33WD 'Type Inj. W TVD 1906 IA 443 1707 1667 1658 1655 P.T.D 1801140 ' TypeTest SPT Test psi I 1500 • i OA Interval ETA - P/F P ` Tubing 550 L 550 550 550 550 Notes: Initial post RWO MIT. 0.25 BBLS diesel pumped. OA is cemented to surface. (( ke4 -c c --rac IA- MAP_ 0 21 Friday, March 25, 2011 Page 1 of 1 Mar 23 11 05:29p Jeff Jones 907-75277 p.2 • , .. Swanton Rive Unit SRU 31-33170) vvoisgo..-0.31rte Actual Wellbore Schematic '015dirteddflittiO? . — RIM = 184' KG / GL: 166' ANISL K13.414F =14.92' i i • 1 _ a 3 3' • '.' !, 'ti ' ' ; • : ' ,-. Size Type Wt/ Grade Top Btm CONN ( ID Cement 1 Other - • ' •• • • 10-3/4" Conductor - Surface 90' - Driven :. 1 • - • 7" Surface 29#, K-55 Surface 2,461' 8RD / 6.059" 800 sx/ Cmt to surface ..... - ..•:, 17#, N-80 13TC 1 4.892" 100 sx / Cmt to surface •.": 5-1/2° Protective - Surface 2,015' J4----0- , 20#, N-6(1 8RD i 4 778' 1 (Drift of 5-1/2" 20# = 4.653°) -;'. •;•• ; -,,!` Tubing 7.: '•'.. -"77 2-7/8" I Production I 6.5#, N-80 I Surface I 1.923' i 6RD / 2.441" I Cplg OD .= 3.668" ... ..„ .:',..IY : - :•., -!1%.-r.-,." :,.: --,;.--: • f - - , ';:!,(.?; .; . Production String Jewelry Detail Depth (RKB) Length ID 00 Item - • -. 1, 7- -: •::, , :: 1 - 1 19' 0.50 2.441" 3.668" Tubing Hanger, 2-7/8" (8RD suspension threads) 2 1,917' 5.92' 2.375" 3.000" G-22 Tubing Locator Seal Assembly (5.13' seals) ..-- *•. ' 1 3 1,917' 2.12' 3.000" 4.437" Packer. Baker F-1 (set hydraulically 9/22185) 4 1,923' 0.60' 2.441" 2.875" Tubing Tait, 1 12 Mule Shoe ...... • .., 5 2,413' 2.0' - - FISH] Bridge Plug, Baker Model N-1 to 9/22185) 2.413' - - - , FISH] Packer, Baker Model P-1 (tag 9/22/85) , •_,,.. - -1=1"--111 • .... '- '..-4 .„4. • —411: -,li ; 3 -':--";.• 4 ,,';!, - , ... •-• :' '-':. :"..., ;., Perforation Data ' ZONE TOP BTM SPF Condition Sterling 2,100' 2,140' 4,4 2-1/8' VVL (8/21/89) / 4° H.S.C. (1/2° EH), (8/25/81) : ' -. ' • .i Sterling 2,162' 2242' 4,4 2-1/8" VVL (8121/89)14" H.S.C. (1/2" EH), (64/25/81) Z ,••••, s-mt- 6" .)j - Sterling 2,256' 2,284' ' 4,4 2-1 /8° WL (8/21/89)1 4" H.S.C. (1/2" EH), (8/25/81) f/.31 y ., ,!- r • . Sterling : 2,313' 2,383' 4.4 2-1/B' WI (8/21/69J/4' H.S.C. (1/2" EH), (8/25/81) (Tag wi I . . ,,," ' °. 2.26' dummy gun' : ''''' . ' ...t; -•-• - A''' 1 0. . 4113110) . 7' 4 e,.. ‘• ':.:A3tr:"4*: 1 — g -- Staling 7 .174r104.k ..._-. .. • ;,,,,%.'i *-,.yiyani, ,-_- -.,- :,-.',...'..) .•_,11, rA.,\ti---.9.1.,i_ , ::: 60eNnexi: (Tag S12249 . ; .4 ...,,- .m . ...m:, t 7' 2,461 TO =2,481' ?STD =2,413' Directional Data: max hole angle = 0.5° at 2,450' MD SRU 31-33WD Schematic 4-13-10 doe Updated by STP 4-13-10 • • C l I ! p ' 1 r SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS e` � 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / ANCHORAG�E07ALASSKA399501 -3539 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL Area Injection Order 13A.001 Mr. Dave Whitacre Union Oil Company of California �� P.O. Box 196247 Anchorage, AK 99519 -6247 y RE: Area Injection Order 13A Request for Administrative Approval . ) 0‘, Rule 2: Authorized Injection Strata for Disposal a> Swanson River Field Dear Mr. Whitacre: °LC) A-VI) \_ In accordance with Rule 9 of Area Injection Order ( "AIO ") 13A.000, the Alaska Oil and Gas Conservation Commission (Commission) hereby GRANTS Union Oil Company of California's (Unocal) request for administrative approval revising the authorized injection strata for injection disposal of Class II oil field wastes to the strata that are common to, and correlative with, strata between the measured depths (MD) of 1,745 feet and 3,460 feet in Swanson River Unit (SRU) well No. 32 -33 (SRU 32 -33). FINDINGS 1. Within the Swanson River Field, all aquifers deeper than 1,700 feet below ground surface are exempted per 40 CFR 147.102 (b)(1)(i). 2. Strata receiving Class II injected waste materials are sandstones assigned to the "B- series" of the Pliocene -aged Sterling formation. These stacked, fluvial sandstone strata are typically 10- to 50 -feet thick, rich in volcanic rock fragments, fine -to coarse - grained, fairly to moderately sorted, and display little detrital or authigenic matrix. Well -log correlations indicate local continuity of the sandstone strata is good. 3. Upper confinement for injected waste is provided by a 30- to 50 -foot thick interval of interbedded layers of claystone and siltstone with minor sandstone that lies between 1,695 feet and 1,745 feet MD in SRU 32 -33 (see Figure 1, below). This confining interval is present on well logs and appears to be continuous for a radius of '/2 mile around the active SRU 31 -33WD and SRU 32 -33WD disposal wells. 4. Lower confinement for injected waste is provided by a 115 -foot thick interval that lies between about 3,460 feet and 3,575 feet MD in SRU 32 -33. This interval contains an aggregate thickness of about 55 feet of interbedded claystone, siltstone and coal that will provide an effective bottom seal for the injected fluids. This confining interval appears to be continuous for a radius of 'A mile around SRU 31 -33WD and SRU 32 -33WD. • • MO 13A.001 February 17, 2011 Page 2 of 4 CscrePtles D.,,M1 R..1. P_...,, SP .0 128 ,00-01 0002 150 MV 50 2.2 oFMM 2000105 0✓89 2.5.. TVD SS> R0( .15,+1 nw11CNS1 0.2 01T48 200040 % C TVD DTCP(D11 250 US, 10C <MD -1900 1600 1600 Confining 1700 ,900 -1600 Interval 690 1800 1900 .1900 1900 1900 _1800 2000 2000 -1800 2100 2100 2200 0000 2200 Perforated Intervals in 2300 2500 SRU 31 -33WD and 2400 0900 2200 } SRU 32-33WD ..:.tea 0500 2500 zsoo - - -. Revised Disposal 2600 2500 -2.00 Interval — _ _ 2600 2700 2900 ..,. 2800 0600 -2800 • 2900 2900 -2700 -2800 — 3000 2000 .. -2900 _ _ _ .. 3100 .1 00 q -8000 . 3200 0200 -4100 3300 0000 - -8200 • I 3400 5900 r 3800 Confining 3500 .600 i Interval -4900 -.. 3600 .600 Figure 1. SRU 32 -33 Well Log AIO 13A.001 February 17, 2011 Page 3 of 4 5. To date, approximately 62.3 million barrels of Class II wastes have been injected into wells SRU 21 -33WD, SRU 31 -33WD, SRU 32 -33WD, and SRU 41 -33WD. Wells SRU 21 -33WD and SRU 41 -33WD have been properly plugged and abandoned, but during disposal injection operations these two wells received 2.7 and 3.7 million barrels of waste, respectively. Wells SRU 31 -33WD and SRU 32 -33WD are active injection wells that have received 32.7 and 23.2 million barrels of waste, respectively. 6. The cumulative injected Class II waste volume is estimated to extend radially about 800 feet from SRU 31 -33WD and about 650 feet from SRU 32- 33WD. Waste volumes injected into SRU 31 -33WD and SRU 32 -33WD are likely in communication with each other. 7. Rule 2 of AIOs No. 13 and 13A defines the authorized injection strata as "...those strata which correlate with strata found in well SRU 32 -33 between the measured depths of 2,100 feet and 3,460 feet." The injection strata were defined in accordance with descriptions provided by ARCO Alaska, Inc., operator for the SRU at the time of the original application. 8. Upper confining intervals for the Sterling injection sands are not precisely defined in the original application for AIO 13. The depth of 1,700 feet is referenced in that application and in AIO 13 as being the upper limit for confinement. 9. On May 13, 2010, Unocal requested the Commission revise AIO 13 to conform to the well logs. 10. The Alaska Department of Natural Resources' MapGuide Water Rights GIS System (http: / /magellan.dnr. state .ak.us /dnrwater /default.cfin) shows 10 shallow water wells recorded in the SRU area; the deepest is 262 feet below ground level. All wells are registered to Unocal and dedicated to supporting oil and gas activities; no other registered water wells are within 6 miles of the SRU. 11. Active disposal injection wells SRU 31 -33WD and SRU 32 -33WD recently passed standard mechanical integrity tests. CONCLUSIONS 1. The proposed, revised injection strata that are equivalent to strata between 1,745 and 3,460 feet MD in well SRU 32 -33 are sufficiently thick and laterally continuous and have sufficient reservoir properties to accept additional injected Class II waste fluids. This estimate is based on the temperature -log- determined waste depths of 1,970 feet MD in 1989 and 1,800 feet MD in 2010, assuming uniform filling of the 170 -foot thick interval at 8.1 feet per year, an average porosity of 21.5 %, and piston -like displacement of native formation fluids. 2 ARCO Alaska, Inc., 1987, Swanson River Unit, Area Injection Order Application for AIO 13. Attachment G -2 is hand - annotated with the injection interval between 2,100 feet and 2,422 feet MD. Attachment G -2 is described on page 12 as "an electric log showing the water injection zones in a typical water injection well." However, page 11 states: "Injection within the Sterling is limited to water wet sandstones within the Sterling B series (as recognized by Chevron Stratigraphy) from 2,100' to 3,500'." A10 13A expanded the definition of the underlying Hemlock Pool, but it did not alter the definition for the Sterling injection sands or address the associated Sterling confining intervals. 3 ARCO Alaska, Inc., 1987, cited above. Subsection 2, states in part: "Even if the immediate confining zone failed, there are several confining zones between the injection interval and 1700'.'° Finding 4 of AlOs 13 and 13A states: "Adequate confining strata are present below 1700 feet in the Swanson River Field to prevent upward movement of waste fluid from injection zones into non- exempt fresh water sources." 1 • A1O 13A.001 February 17, 2011 Page 4 of 4 2. The upper and lower confining intervals designated in the SRU 32 -33 well, confirmed on the well logs submitted in support of the original application, are sufficiently thick and laterally continuous to contain injected waste fluids. 3. There is no evidence that injected waste fluids have migrated or will migrate upward beyond the upper confining layer into non - exempt strata. Underground sources of drinking water will not be affected. 4. The active disposal injection wells have demonstrated mechanical integrity. 5. Revising the authorized injection strata will not promote waste or jeopardize correlative rights, is consistent with the well logs submitted in support of the original application, is based on sound engineering and geoscience principles, and will not result in an increase risk of fluid movement into fresh water. NOW, THEREFORE, IT IS ORDERED THAT the rule governing Class II underground injection operations in the Swanson River Field as described in Rule 2 of Area Injection Order No. 13A be revised as follows: Rule 2 Authorized Injection Strata for Disposal (Revised AIO 13A.001) Within the affected area non - hazardous oil field fluids may be injected for the purpose of disposal into strata defined as those strata that are common to, and correlate with, strata f. - • well SRU 32 -33 between the measured depths of 1,745 feet and 3,460 feet. 'Lt o DONE at Anchorage, Alaska and dated February 17, 2011. , i az, Daniel T. Seamount, Jr. .� No ' .n Cath P. Foerster Chair omm s' . er Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Cormnission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter detennined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be tiled within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. STATE OF ALASKA • ALASKA~L AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~~ o8(3t~te9le9 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Fill Cleanout Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 180-114 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic ^ Service ~ .API Number: 50-133-20336-00 7. PropertXDesignation (Lease Number): 8. Well Name and Numbe . FEDA028399 [Swanson River Unit] Swanson Riv Unit (SRU) 31-33WD 9. Field/Pool(s): ~ Swanson River Field /Undefined WDSP 10. Present Well Condition Summary: Total Depth measured 2,461 feet Plugs (measured) N/A feet true vertical 2,461 feet Junk (measured) 2,393 (fill) feet Effective Depth measured 2,393 feet Packer (measured) 1,906 feet true vertical 2,393 feet (true vertical) 1,906 feet Casing Length Size MD ~ TVD Burst Collapse Structural Conductor 90' 10-3/4" 90' 90' Surface 2,461' 7" 2,461' 2,461' 5,610 psi 5,410 psi Intermediate Production Liner 2,015' 5-1/2" 2,015' 2,015' 7,740 psi 6,290 psi / Perforation depth: Measured depth: 2,100'-2,140', 2,162'-2,242', 2,256'-2,284', 2,313'-2,383' True Vertical depth: 2,100'-2,140', 2,162'-2,242', 2,256'-2,284', 2,313'-2,383' / 1,926' TVD Tubing (size, grade, measured and true vertical depth): 3-1/2" 9.2# L-80 1,926' MD Packers and SSSV (type, measured and true vertical depth): Baker S-3 Packer 1,906'MD(1,906'TVD) N/A I 11. Stimulation or cement squeeze summary: Intervals treated (measured): + ~ ~~11'1f ,;11a `~ ~ Z~~ Treatment descriptions including volumes used and final pressure: ]~~~~` ,'}""`,` ~? ~ ~'(.~.~ ~~1'~A)IISSIOn N/A ~ ,, , . , ,-, 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 psi 0 psi Subsequent to operation: 0 0 0 0 psi 0 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development^ Service ^~ Daily Report of Well Operations X 15. Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ~ _ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-211 Contact Jack Newell 263-7832 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276-7600 Date 8/26/10 R~D~as au~ 2 Form 10-404 Revised 7/2009 Submit Original Only Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SRU 31-33WD SWANSON RIV UNIT 31-33WD FEDA028399 5013320336_ OM7873 163.00 Jobs - _ --- _ , ~ Primary Job Type Job Category _ Objective Actual Start Date Actual End Date Well Preparation Major Rig Set WRP plugs and Mobilize Key Energy Rig #3. 7/27/2010 7/31/2010 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number SRU 31-33WD 501332033600 _ 1801140_ Daily Operations __ 3/28/2010 00:00 - 7/29!2010 00:00 _ Operations Summary R/U E-line. RI and set WRP plug at 180' WLM. POOH. Test plug to 3,250 psi for 15 min -test OK. RIH and set second WRP plug at 15' WLM. POOH. Test plug to 3,500 psi for 15 min -test OK. R/D E-line. - _ 7/29/2010 00:Q0 -°713012010 00:00 Operations Summary Prep pad and mobilize in equipment. Notify Jim Regg with AOGCC and Tom Zelenka with BLM of upcoming BOP test. AOGCC to send out Bob Noble to witness BOP test. BLM waived witness. - - _- __ ., 7/30/2010 00:00 - 7/31/2010 00't00 _ __ _ _ _ _ Operations Summary Mobilize in Key Energy Rig #3. Spot assocaited equipment. Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (R) Water Depth (R) SRU 31-33WD SWANSON RIV UNIT 31-33WD FEDA028399 5013320336 - OM7873 163.00 J bs --- _ Primary Job Type _ Job Category _ Objective Actual Start Date Actual End Date Clean-Out Major Rig Cleanout Fill and Replace completion 7/31/2010 Work Over (MRWO) Primary Wellbore ARected Wellbore UWI Well Permit Number SRU 31-33WD 501332033600 1801140 _ Dail O erations _ _ __ ?131/2010 00:00 - 8/112010 00:00 __ _ _ Operations Summary / Notifed AOGCC and BLM of upcoming BOP test on 7/29/2010. N/D Tree. N/U BOPE. Test BOPE to 250 PSI Low/ 3000 PSI High.Test - OK. Bob Noble with AOGCC onsite to witness test. 811 /201.0 00:00: = 8/2/2010 00:00 __ Operations Summary R/U slickline. POOH w/ WRP plugs at 15' WLM and 180' WLM. R/U E-line. Cut tubing at 1,907' WLM. RD E-line. Spear tubing and POOH w/ 2-7/8" tubing. PU overshot to retrieve tubing stub and 2-7/8" seal assembly from packer. RIH on 2-7/8" workstring. Catch fish. POOH with tubing stub and complete seal assembly. - --_ $/2/2010 00:00 - 8/3/2010 00:00 _ Operations Summary P/U packer milling assembly. RIH on 2-7/8" workstring. Mill packer. Circulate btms up. POOH w/ full recovery of packer. P/U bladed junk mill, 5-1/2" casing scraper, and bumper sub, jars, and collars. RIH w/ assembly to 1980' RKB. Circulate btms up. POOH with assembly. R/U E-line. Test lubricator to 300 PSI -test OK. RIH with GR/CCL to 1975' WLM. POOH. P/U 5-1/2" WRP. RIH and set at 1515' WLM. POOH. R/D E-line. Test WRP to 1,600 PSI for 15 minutes. Final pressure 1,550 PSI. N/D BOPE. 8/3/2010 00:00 - 8!4!2010 00:00 _ _ _ _ _ - _ - _-_ __ Operations Summary N/D BOPE. Install new tubing spool. Test seals to 250 PSI Low/ 3000 PSI High for 30 mins -test OK. N/U BOPE. Shell test to 250 PSI Low/ 3000 PSI High for 30 mins -test OK. R/U slickline. P/U pulling tool to pull 5-1/2" WRP at 1515' SLM. RIH several times with slickline, no success. P/U 2-7/8" workstring. RIH with 5-1/2" WRP pulling tool. Latched and pulled. POOH with 5-1/2" WRP. 8/4/2010 00:00 -8/5/2010 00:00 _ _ Operations Summary POOH w/ 5-1 /2" WRP. P/U cleanout BHA. RIH and tag fill at 2,042' RKB w/ 10K down. Cleanout fill from 2,042' RKB to 2,385' RKB (2,393' Original RKB). Circ btms up. POOH. UD cleanout BHA. P/U 5-1/2" packer and 3-1/2" tubing. RIH and land tubing hanger w/ packer at 1,898' (1,906' Original RKB). Notified Jim Regg w/ AOGCC 24 hour.notice of planned workover MIT. -- - - 8/5/2010 00:00 - 8/6/2010 OOc00 _ _ _ i Operations Summary Test hanger seals to 4,250 psi for 10 min -test OK. Displace annulus w/ inhibited packer fluid and 5 bbl freeze protection (diesel). R/U slickline. RIH w! N-Test tool to XN-profile at 1,910' RKB (1,918' Original RKB). Unable to get pumps to hold 4,500 psi. Troubleshoot pumping equipment. Mobilize backup pumping equipment. Pressure up to 5,000 psi down tubing to set packer. Hold 5,000 psi on tubing for 15 min -test OK. POOH w/ N-Test tool. R/D slickline. Performed workover MIT of 5-1/2" x 3-1/2" annulus w/ packer at 1,906' MD/TVD. Pressure test to 1,650 psi for 30 min. Final pressure 1,630 psi - test OK. Rig Down. Set BPV. N/D BOPE. N/U Tree. Test hanger void to 2501ow / 5000 psi high for 30 min each -test OK. Pull BPV. Set TWC. Test tree to 2501ow / 5000 psi high for 30 min each -test OK. Pull TWC. Prep for rig move to SCU 34-08. 10.3 ~~ b•112 ~ z,~ Clsai 2,39: PBT[ 2,413 (Tag 7" ~ 2,461' Casing and Tubing Detail (all depths correlated to original RKB of 184') Size Type Wt/ Grade Top Btm CONN / ID Cement /Other 10-3/4" Conductor - Surface 90' - Driven 7" Surface 29#, K-55 Surface 2,461' 8RD / 6.059" 800 sx / Cmt to surface " 17#, N-80 ' BTC / 4.892" 100 sx / Cmt to surface 5-1/2 Protective 20#, N-80 Surface 2,015 8RD / 4.778" (Drift of 5-1/2" 20# = 4.653") Tubin all de the correlated to on final R KB of 184' 3-1/2" Production 9.2#, L-80 Surface 1,926' TC-II / 2.992" Cou lin OD = 3.887" Produc tion Strin Jewel Detail all de the correlated to on final RKB of 184' # De th RKB Len th ID OD Item 1 18' 0.80' 3.991" 6.990" Tubin Han er, 3-1/2" MCA lift threads 2 1,906' 5.89' 2.800" 4.469" Packer, Baker S-3 set h draulicall 3 1,918' 1.06' 2.635" 3.938" XN Ni le 2.635" No- o 4 1,924' 1.32' 2.867" 3.938" WLEG btm at 1,926' 5 2,413' 2.0' - - FISH Brid a Plu ,Baker Model N-1 to 9/22/85 6 2,413' - - - FISH Packer, Baker Model F-1 to 9/22/85 Perforation Data ZONE TOP BTM SPF Condition Sterlin 2,100' 2,140' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8/25/81 Sterlin 2,162' 2,242' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8/25/81 Sterlin 2,256' 2,284' 4,4 2-1 /8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8/25/81 Sterlin 2,313' 2,383' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8/25/81 terling TD =2,461' PBTD =2,413' Directional Data: Maximum hole angle = 0.5° at 2,450' WBD SRU 31-33WD Actual 8-05-10 docx Uodated by STP 8-05-10 RKB = 1b4' KB / GL:16b' AMSL KB-THF =18.02' STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS WGk-- o$~Sl~Zofo 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Run Press/Temp Survey Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: ~. Permit to Drill Number: Name: Development ^ Exploratory ^ 180-114 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^ .API Number: 50-133-20336-00 7. Property Designation (Lease Number): 8. Well Name and Number! FEDA028399 (Swanson River Unity Swanson Riv Unit (SRU) 31-33WD 9. Field/Pool(s): Swanson River Field /Undefined WDSP 10. Present Well Condition Summary: Total Depth measured 2,461 feet Plugs (measured) N/A feet true vertical 2,461 feet Junk (measured) 2,089 (fill) feet Effective Depth measured 2,089 feet Packer (measured) 1,917 feet true vertical 2,089 feet (true vertical) 1,917 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 90' 10-3/4" 90' 90' Surface 2,461' 7" 2,461' 2,461' 5,610 psi 5,410 psi Intermediate Production Liner 2,015' S-1 /2" 2,015' 2,015' 7,740 psi 6,290 psi Perforation depth: Measured depth: 2,100'-2,140', 2,162'-2,242', 2,256'-2,284', 2,313'-2,383' True Vertical depth: 2,100'-2,140', 2,162'-2,242', 2,256'-2,284', 2,313'-2,383' Tubing (size, grade, measured and true vertical depth): 2-7/8" 6.5# N-80 1,923' MD 1,923' TVD Packers and SSSV (type, measured and true vertical depth): Baker F-1 Packer 1,917'MD(1,917'TVD) N/A N/A 11. Stimulation or cement squeeze summary: _ m Intervals treated (measured): N/A ° ~` AlJ fa 2 ~ 2 01 G Treatment descriptions including volumes used and final pressu-^~'~'W ~~- ~~ ~^~' ~~ N/A ~~~SIt~ ~' ~ ~Pfl~<, ~t~-°t'!CCIISSIOft 12. Representative Daily Average Production or Injection Da ';a ~ Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 psi 0 psi Subsequent to operation: 0 0 0 0 psi 0 psi 13. Attachments: 14. Well Class after work: ~ Copies of Logs and Surveys Run N/A Exploratory^ Development^ Service ^~ Daily Report of Well Operations X 15. Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ ~ WIND ~ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-213 Contact Jack Newell 263-7832 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276-7600 Date 8/26/10 RBDI IBS AU6 2 7 ~ Form 10-404 Revised 7/2009 - ~ Submit Original Only Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ff) SRU 31-33WD SWANSON RIV UNIT 31-33WD FEDA028399 5_013320336 OM7873 163.00 Jobs . __ _ _ _~~_ _ Primary Job Type Job Category Objective Actual Start Date Actual End Date Well Preparation Major Rig Set WRP plugs and Mobilize Key Energy Rig #3. 7/27/2010 7/31/2010 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number SRU 31-33WD 501332033600 1801140 _ Dail r~Operattorts - ~ __ 7/25/2010 00:00 - 7/26/2010 00:00 - - - - - - - Operations Summary Conduct PJSM. R/U Slickline. RIH w/ pressure/temperature tool and log from surface to 2,050'. POOH. R/D Slickline. _ __ ._ _. 7/27/2010 00:00 - 7/28/2010 00:00 __ __ Operations Summary Conduct PJSM. R/U pumping equipment. R/U lines and test to 1,500 psi. Pump 481 bbl cold water at maximum pressure of 680 psi. R/U Slickline. RIH w/ pressure/temperature tool and log from surface to 2050' SLM. POOH to 1000' SLM. Make 3 logging passes from 1000' SLM to 2050 SLM. POOH. R/D Slickline. • • Chevron I Well: ISRU 31 -33wd r Field:JSwanson River 107 -27 -2010 Pressure (psia) 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1000 s�iiC � � Em gli t �. E. -- C CCC _ t I- : - a 1100 Pressure- Temperature Profile COI - _ 1. Going in hole to 2069 Overlay — -- M 2 Well Shut -In � ■ _ - _- 9 1' 1200 m - _ 1300 - : = _ = _. ....._ I NI #1 =_ r 1- rim 1 . iii. _ __ is II _ a , ri 400 � ON 1 500 S � �„ _ _ _ ,_ . 1 i II 1 w t _ _ _ _ ?_ �. � �� 1600 Ii CL --- 1111011 ca k - 1700 mash_ = --- .� • 'i t om' E F �;i� =_ _ MZ - lam 14 O 1900 �- — " Il� _ _ 9 o �_� X111 5000 Ear - 2100• i f , } 1 f 50 55 60 65 70 75 80 85 90 95 100 Temperature (Deg. F) - Perfs x PKR •10 3/4" 7" •2 7/8" — 51/2" —1st Pass Temp —7-25-10 Temp - min Pass Temp 1 hr Pass Temp 2 hr Pass Temp -4-15-10 Temp Report date: 8/2/2010 eVl'O Swanson River Unit SRU 31-33WD Well SRU 31-33WD Actual Wellbore Schematic Upd t d 4/15% 09/23/85 Fa(B=784 KB/GL 766'AMSL KB-T}F =19.02' Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement /Other 10-3/4" Conductor - Surface 90' - Driven 7" Surface 29#, K-55 Surface 2,461' 8RD / 6.059" 800 sx / Cmt to surface " 17#, N-80 ' BTC / 4.892" 100 sx / Cmt to surface 5-1/2 Protective 20#, N-80 Surface 2,015 8RD / 4.778" (Drift of 5-1 /2" 20# = 4.653") Tubing 2-7/8" Production 6.5#, N-80 Surface 1,923' 8RD / 2.441" C I OD = 3.668" Produc tion Strin Jewel Detail # De th RKB Len th ID OD Item 1 19' 0.50' 2.441" 3.668" Tubin Han er, 2-7/8" SRD sus ension threads 2 1,917' 5.92' 2.375" 3.000" G-22 Tubin Locator Seal Assembl 5.13' seals 3 1,917' 2.12' 3.000" 4.437" Packer, Baker F-1 set h draulicall 9/22/85 4 1,923' 0.60' 2.441" 2.875" Tubin Tail,'/2 Mule Shoe 5 2,413' 2.0' - - FISH Brid a Plu ,Baker Model N-1 to 9/22/85 6 2,413' - - - FISH Packer, Baker Model F-1 to 9/22/85 Perforation Data ZONE TOP BTM SPF Condition Sterlin 2,100' 2,140' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8/25/81 Sterlin 2,162' 2,242' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8!25/81 Sterlin 2,256' 2,284' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8/25/81 Sterlin 2,313' 2,383' 4,4 2-1/8" WL 8/21/89 /4" H.S.C. 1/2" EH , 8/25/81 Stering 7" ~ 2,467' TD=2,461' PBTD=2,413' Directional Data: max hole angle = 0.5° at 2,450' MD SRU 31-33WD WBD 6-04-10.doc Updated by STP 4-15-10 • • Page 1 of 1 Regg, James B (DOA) ~ ~ ~v-/~`~ From: Greenstein, Larry P [Greensteinlp@chevron.com] ~~ jt~'4~ Sent: Monday, August 09, 2010 5:50 PM ~~~ I To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Cc: Merle, Greg L; Wafgenbach, Christopher; Bush, Robert E; Myers, Chris S; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)]; Eastham, Kevin (KEastham) Subject: MIT Swanson_08-05-10 Attachments: MIT_Chevron_ 08-05-10.x1s ~ Here is the successful workover MIT performed, but not witnessed, 0 8 /10 for SRU 31-33WD. Larry t ~~~~. ,~. ~ ! _ . ~ w 1 ~,. ~ .. 8/10/2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~ ~ ~ It~~~o Email to:jim.regg@alaska.gov; phoebe brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.go~ OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Union Oil Company of California Swanson River Unit /SRU 31-33WD 08/05/10 Mena ace/Smith AOGCC notified 8/4 -waived witnessing Packer Depth Pretest Initial 15 Min. 30 Min. Well SRU 31-33WD Type Inj. N ' TVD 1,906" Tubin 0 0 0 0 Interval T P.T.D. 180-114 T pe test P Test psi 1500 Casin 0 1,650 1,630 1,630 P/F P Notes: OA 0 0 0 0 Well T pe Inj. TVD Tubing Interval P.T.D. T pe test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. T pe test Test psi Casin P/F Notes: OA Well Type In'. TVD Tubin Interval P.T.D. T pe test Test psi Casin P/F Notes: OA Well Type In'. TVD Tubin Interval P.T.D. Type test Test psi Casin P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT_Chevron_ OS-05-10.x1s Page 1 of 2 Hubert, Winton G {DOA) From: Hubert, Winton G (DOA) Sent Tuesday, July 27, 2010 8:17 AM To: 'PORHOLA, STAN T Sub~ct: RE: Revised procedure for SRU 31-33WD Sundry 310-211 Sta n Thanks, I ~ntill ,add the foregoing to existing a~praved Sunda 31~;-211. Winton Hubert ~- ~' , 793-~ 231 - From: PORHOLA, STAN T [mailto:stan.porhola@chevron.com] Se~rt: Tuesday, July 27, 2010 7:56 AM , To: Hubert, Winton G (DOA) Cc: Kanyer, Christopher d abject: RE: Revised procedure for SRU 3i-33WD Sundry 310-211 ~ivintan Per our phone discussion, 'vV?'v+~ill move fC~'uvaPd ~NI<ih arcl~oring tl;e test j=amts ~~ dG a fu? ~~~~ test before ~,e.~llinq tl~e hang= as pr€~pased in our original ap~:raveµ Sundry 31;?-211, PTD 18th-114. Vie are still requesting tc rerncve the USE? It~g r'.~n. If you gave any questions, feel free to cc~rrtact one. Stan Porhota~~ Drilling engineer IVIidCcrttisae€ttlAlaslia ~i~ssness U~lt Chevron Nactl~ America ~xpla;atien and Prc~duct;ar 380 Center~,cint Dr. Suite 1~c; ,~rchorage> AIC 99~G3 Tel 9~7 263 764u Fax 9t?7 263 7884 Cell 9117 229 1 769 stan.porhala a~chevron.cam a( r!i Cont±dzntia! Font r PrivilegedjConfidential information maybe contained ir-t, or a~~actred to, this message. If you are not the addressee indicated in this message (or responsible for de;ivery of the message to such person i, you may not cop.v, forward, disclose, deliver, or othervrise use this message ar any part of it in any form whatsoever. If your receive the message in error, you should destroy this message after notit',ring me immediately by replying to the message or contacting me at (907) 263- 7640. From: Hubert, Winton G (DOA) [mailto:wintnn.aubert@alaska.gov] Sent: Friday, July 23, 2010 8:12 AM To: PORHOLA, STAN T Subject: RE: Revised procedure for SRU 31-33WD Sundry 310-211 Stan, Page 2 of 2 ArJGCC 7~3-1 X31 From: PORHOIA, STAN T [mailto:stan.porhola@chevron.com] Sent: Thursday, July 22, 2010 2:59 PM To: Aubert, Winton G (DOA} Cc: Kanyer, Christopher V; Newell, Jack R [Swift]; Nienhaus, Doug R Subject: Revised procedure for SRU 31-33WD Sundry 310-211 Winton, Attached is a revised procedure summary for approved Sundry 310-211, PTD 180-114. Due to wom threads on the existing tubing hanger, we wi11 not be able to land a test joint for the initial BOPE test. We are proposing the folk~nring: 1.) Shell Test the ROPE to 250 psi low/3000 psi high 2.) Cut the tubing above the packer 3.) Pull the oki tubing hanger and 1 joint below 4.) land a new tubing hanger with adequate hanger threads 5.) Pertorm a complete BOPE test to 250 psi low/3000 psi high Additionally, we are proposing the following: 1.) Remove the USIT log run If you have any questions, feel free to contact me. Stan Porhola• Drilling Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tel 907 263 7640 Fax 907 263 7884 Cell 907 229 1 769 stan.porhola(d,Jchevron.com PrivitegedJConfidential information may Le contained in, or arrached to, this message. If you are not the adds ssee indicated in this message (or responsible for delivery of the message to suctr person}, you may not copy, foravard, disclose, deliver, or other.vise use this message ar any part of it in any farrrr rrhatsceyer. If yov receie the message n error, you should destroy t.`^?s message after notifying me immediately iy repaying to the message or contacting me at {'gg7; 2b3-7b~F~. u • ~~Q~C~ 0~ a~Q~~a /,E..M.~,.w~,~ Timothy C. Brandenburg Drilling Manager Union Oil Company of California .~'~:~',~~}-t ~~%~- ~' ~~~~' P.O. Box 196247 Anchorage, AK 99519 Re: Swanson River Field, Undefined WDSP Pool, SRU 31-33WD Sundry Number: 310-213 V~ J Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of July, 2010. Encl. U ° (~ ~j STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1~14~ ot(t4(La-o 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-enter Susp. Well ^ Stimulate ^ Alter Casing ^ Run PressurelTemperature Survey ^~ 2. Operator Name: 4. Current Well Class: .Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 180-114 3. Address: g p ^ Service ^~ . Strati ra hic 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-20336-00 , 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^~ Swanson Riv Unit (SRU) 31-33WD - 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028399 [Swanson River Unit] ~ Swanson River Field /Undefined WDSP 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 2,461 _ 2,461 2,413 2,413 N/A 2,089' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 90' 10-3/4" 90' 90' Surface 2,461' 7" 2,461' 2,461' 5,610 psi 5,410 psi Intermediate Production Liner 2,015' S-1 /2" 2,015' 2,015' 7,740 psi 6,290 psi Pertoration Depth MD (ft): ~j Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 2,100'-2,140', 2,162'-2,242', 2,100'-2,140', 2,162'-2,242', 2 7/8" 6.5# N-80 1,923' 2,256'-2,284', 2,313'-2,383' 2,256'-2,284', 2,313'-2,383' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker F-1 Packer! N/A , 1,91TMD (1,91TTVD) / N/A 12. Attachments: Description Summary of Proposal ^~ .Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development ^ Service ~- 14. Estimated Date for 7/23/20 .Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ WDSPL ^~ Plugged ^ 16. Verbal Approval: Date: N/A WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Newell 263-7832 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276-7600 Date 7/15/2010 ~ COMMISSION USE ONLY witness Sund Number: "~~ 3 t a re resentative ma C diti f l N tif C i i th ry on ons o approva : o y omm ss on so a p y Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ .Location Clearance ^ ~~~~~® Other: ~ ~~~ ~ ~ 201 Alaska Oil- €~ Gaa Ceiu. Commigsio Subsequent Form Required: ~ I - ~0 4-. ~rctrer3~e APPROVED BY A 1S ' (/ Approved by: COMMISSIONER THE COMMISSION ~'~ '~ Date: `J ~ouM~ JUL ~ ~O~~L, Form 10-403 Revised 12/2009 ~ ~ ~ ~ I Submit in Duplicate Chevron • , Swanson River Unit Well #SRU 31-33WD 7/15/10 OBJECTIVE: /~ • To determine the interval(s) receiving disposal water utilizing cold water pump-in temperature survey. PROCEDURE SUMMARY: 1 RU Slickline. Pressure test lubricator to 250psi low/2500psi high. /° 2 RU Pumping equipment. Pressure test lines to 1000 psi. 3 Pump (+/-) 500 bbl of cold water (+/- 45°F) down the tubing. Do not exceed 985 psig (1000 psia). 4 RIH w/ pressure/temperature survey to (+/-) 2089' RKB. 5 Repeat steps 4 for a minimum of 3 total passes. 6 POOH. RD Slickline. RD Pumping equipment. 7 Turn well over to production. Shut in pending approval to re-commence injection. `~ Current BHP: 928 psi @ 2100' TVD Max Downhole Pressure: 1425 psi @ 2100' TVD (Determined with Pressure/Temperature Survey ran 4/15/10) j MASP: 1215 psi (Based on a pressure gradient of 0.1 psi per foot of true vertical depth) SRU 31-33WD REVISED BY: STP 7-15-10 evro SRU 31-33WD Well SRU3i1 3 WD Actual Wellbore Schematic Upd t d 4/115/ 09/23/85 1o-y4' ~~ san^ ~ z,o1s Topof Fill 2,089' RKB (Tag Nd 2.25" bailer 4/15/10) PBTD ?.413' RKB (rag 9122/8! 7" ~ 2,461' Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement /Other 10-314" Conductor - Surface 90' - Driven 7" Surface 29#, K-55 Surface 2,461' 8RD / 6.059" 800 sx / Cmt to surface " 17#, N-80 ' BTC / 4.892" 100 sx / Cmt to surface 5-1/2 Protective 20#, N-80 Surface 2,015 8RD / 4.778" (Drift of 5-1 /2" 20# = 4.653") Tubing 2-7/8" Production 6.5#, N-80 Surface 1,923' 8RD / 2.441" C I OD = 3.668" Produc tion Strin Jewel Detail # De th RKB Len th ID OD Item 1 19' 0.50' 2.441" 3.668" Tubin Han er, 2-7/8" 8RD sus ension threads 2 1,917' 5.92' 2.375" 3.000" G-22 Tubin Locator Seal Assembl (5.13' seals 3 1,917' 2.12' 3.000" 4.437" Packer, Baker F-1 set h draulicall 9/22/85 4 1,923' 0.60' 2.441" 2.875" Tubin Tail,'/2 Mule Shoe 5 2,413' 2.0' - - FISH Brid a Plu ,Baker Model N-1 (ta 9/22/85 6 2,413' - - - FISH Packer, Baker Model F-1 to 9/22/85 Perforation Data ZONE TOP BTM SPF Condition Sterlin 2,100' 2,140' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8/25/81 Sterlin 2,162' 2,242' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , (8/25/81 Sterlin 2,256' 2,284' 4,4 2-1/8" WL 8121/89 / 4" H.S.C. 1/2" EH), (8/25/81 Sterlin 2,313' 2,383' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8/25/81 Stering TD=2,461' PBTD=2,413' Directional Data: max hole angle = 0.5° at 2,450' MD SRU 31-33WD WBD 6-04-10 doc Updated by STP 4-15-10 RKB=184 KB/GL 165'AMSL KB-TFF =19.02' 6 0 ~ ~ ~ SEAN PARNELL, GOVERNOR AL.A58A OII. t'usa/ (~S 333 W. 7th AVENUE, SUITE 100 CO1~T5ER~PA'1`IO1~T COMrIISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy C. Brandenburg Drilling Manager ~, Union Oil Company of California $ V '~ P.O. Box 196247 Anchorage, AK 99519 Re: Swanson River Field, Undefined Pool, SRU 31-33WD Sundry Number: 310-211 ~• r~, Dear Mr. Brandenburg: _~-`_,.~~~~s~,~ ~'~;~_. "`' '~~~` Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair '~ DATED this C.5 day of July, 2010. Encl. ~, 45' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 y~lG/~' o r j,s ~Z~`a 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate Q Pull Tubing ^~ Time Extension ^ Operations Shutdown ^ Re-enter Susp. Well ^ Stimulate ^ Alter Casing ^ Fill Cleanout ^~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 180-114 3. Address: Stratigraphic ^ Service Q 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-20336-00 - 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Swanson Riv Unit (SRU) 31-33WD 9. Property Designation (Lease Number): 10: Field/Pool(s): FEDA028399 [Swanson River Unit) ~ Swanson River Field /Undefined WDSP 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 2,461 2,461 2,413 2,413 N/A 2,089' (fill) Casing Length Size MD /' ND Burst Collapse Structural Conductor g0' 10-3/4" 90' 90' Surface 2,461' 7" 2,461' 2,461' 5,610 psi 5,410 psi Intermediate Production Liner 2,015' 5-1/2" 2,015' 2,015' 7,740 psi 6,290 psi Perforation Depth MD (ft): / Perforation Depth ND (ft): / Tubing Size: Tubing Grade: Tubing MD (ft): 2,100'-2,140', 2,162'-2,242', 2,100'-2,140', 2,162'-2,242', 2 7/8" 6.5# N-80 1,923' 2,256'-2,284', 2,313'-2,383' 2,256'-2,284', 2,313'-2,383' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): ' ' Baker F-1 Packer / N/A MD (1,917 ND) / N/A 1,917 12. Attachments: Description Summary of Proposal ^~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development ^ Service ^~ - 14. Estimated Date for /23/3010 15. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ WDSPL ^~ - Plugged ^ 16. Verbal Approval: Date: N/A WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Newell 263-7832 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature r - Phone 276-7600 Date 7/13/2010 COMMISSION USE ONLY mb d N S i er: ~~ O ~~~' un ry u tness Conditions of approval: Notify Commission so that a representative may w ^ ~ ~ Location Clearance Mechanical Integrity Test Plug Integrity ^ BOP Test [ ® ~~~~~ Y 4 Other: ~ ~ S ~ ~d ~ ~ ~© ~ 00 O ~ ~ - ~ 1(.~~, ~ ~ 2~1Q I~ka ~~! & G&t Ge>rus w~~RlMlY1Y Subsequent Form Required: ~p - (.~p [,~ , ~C~«g@ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 7 1 S /~ ~-~ ~ Res :~,~ ~~ 6 ~ 1 ~l NAL Form 10-403 Revise 12/2009 O R Submit in Duplicate Chevron OBJECTIVE: Swanson River Unit Well #SRU 31-33WD 7/12/10 • Pull tubing, remove packer, changeout wellhead, perform fill cleanout, and recomplete with 3-1/2" tubing completion. PROCEDURE SUMMARY: 1 RU Eline. Pressure test lubricator 250psi low/3500psi high. 2 RIH and set retrievable tubing plug at +/- 180' RKB. Test to 3,000 psi. ~ 3 RIH and set tubing plug below hanger (No BPV profile). Test to 3,000 psi. RD Eline. 4 MIRU Key Rig on well. 5 NU BOP, test same to 250psi low/ ,000 i high. 6 Pull tubing plug below hanger. Pull retrievable tubing plug at +/- 180' RKB. 7 RIH and cut tubing at +/- 1,900' RKB. 8 Circulate well with lease water. 9 Pull existing 2-7/8" completion out of Baker F-1 Packer at 1,917' RKB. 10 Mill out and retrieve packer at 1,917' RKB. 11 RIH and set retrievable plug in 5-1/2" casing at +/- 1,500' RKB. Pressure test plug to 1,500psi. °~ 12 ND wellhead. 13 NU new wellhead and test to 1,000 ~;"voids to 3,000psi. ~ 14 NU BOP, test same to 250psi low 3,000psi high. ~~ 15 Pull retrievable plug at +/- 1,500' RKB. 16 Clean out fill from 2,089' RKB to +/- 2,150' RKB, or clean as deep possible (PBTD at 2413' RKB). 17 Run USIT log to +/-2,015' RKB for 5-1/2" casing and cement evaluation. 18 RIH with packer and 3-1/2" tubing completion to +/-1,926' RKB. Set packer at +/- 1,875' RKB, pending evaluation of USIT log. 19 Perform MIT to 1,500psi. 20 RD, demobe Key Rig. 21 Turn well over to production. Shut in pending approval to re-commence injection. Current BHP: 928 psi @ 2100' TVD Max Downhole Pressure: 1425 psi @ 2100' TVD (Determined with Pressure/Temperature Survey ran 4/15/10) MASP: 1215 psi (Based on a pressure gradient of 0.1 psi per foot of true vertical depth) f SRU 31-33WD REVISED BY: STP 7-12-10 evro Swanson River Unit SRU 31-33WD Well SRU 31-33WD Actual Wellbore Schematic Upd t d 4/115/ 09/23/85 ia3/a^ ~' San" ~ 2,018 Top of Fil I 2089' RKB (Tag w/ 2.25" bailer 4N5I10) PBTD 2,413' RKB (rag 9V2?/& 7" ~ 2,461' Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement /Other 10-3/4" Conductor - Surface 90' - Driven 7" Surface 29#, K-55 Surface 2,461' 8RD / 6.059" 800 sx / Cmt to surface " 17#, N-80 ' BTC / 4.892" 100 sx / Cmt to surface 5-1/2 Protective 20#, N-80 Surface 2,015 8RD / 4.778" (Drift of 5-1 /2" 20# = 4.653") Tubing 2-7/8" Production 6.5#, N-80 Surface 1,923' 8RD / 2.441" C I OD = 3.668" Production Strin Jewel Detail # De th RKB Len th ID OD Item 1 19' 0.50' 2.441" 3.668" Tubin Han er, 2-7/8" 8RD sus ension threads 2 1,917' 5.92' 2.375" 3.000" G-22 Tubin Locator Seal Assembl 5.13' seals 3 1,917' 2.12' 3.000" 4.437" Packer, Baker F-1 set h draulicall 9/22/85 4 1,923' 0.60' 2.441" 2.875" Tubin Tail,'/2 Mule Shoe 5 2,413' 2.0' - - FISH Brid a Plu ,Baker Model N-1 to 9/22/85 6 2,413' - - - FISH Packer, Baker Model F-1 to 9/22/85 3 Perforation Data ZONE TOP BTM SPF Condition Sterlin 2,100' 2,140' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8/25/81 Sterlin 2,162' 2,242' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8/25/81 Sterlin 2,256' 2,284' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8/25/81 Sterlin 2,313' 2,383' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8/25/81 Stering TD=2,461' PBTD=2,413' Directional Data: max hole angle = 0.5° at 2,450' MD SRU 31-33WD WBD 6-04-10 doc Updated by STP 4-15-10 RKB=184 KB/GL• 165'AMSL KB-TFF =19.02' 1o-s/a" 90' 6-112" ~ 2,01b' Claanout Fill to minimum 2,140' RKB PBTD 2,41Y RKB (Tag 9/2218 Ii " ~" ~' t t ~J ~~~ Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement /Other 10-3/4" Conductor - Surface 90' - Driven 7" Surface 29#, K-55 Surface 2,461' 8RD / 6.059" 800 sx / Cmt to surface " 17#, N-80 ' BTC / 4.892" 100 sx / Cmt to surface 5-1/2 Protective 20#, N-80 Surface 2,015 8RD / 4.778" (Drift of 5-1/2" 20# = 4.653") Tubing 3-1/2" Production 9.2#, L-80 Surface +/-1,926' TC-II / 2.992" Couplin OD = 3.887" Produc tion Strin Jewel Detail # De th RKB Len th ID OD Item 1 19' 1.50' 2.992" 3.887" Tubin Han er, 3-1 /2" TC-II btm threads 2 +/-1,835' 1.50' 2.813" 3.887" Slidin Sleeve 3 +/-1,875' 3.00' 3.250" 4.500" Packer, Baker SB-3 set h draulicalt ) 4 +/-1,913' 1.50' 2.750" 4.250" XN Nipple (2.750" No- o) 5 +/-1,926' 1.00' 2.992" 3.887" Tubin Tail, WLEG 6 2,413' 2.0' - - FISH Brid a Plu ,Baker Model N-1 to 9/22/85 7 2,413' - - - FISH Packer, Baker Model F-1 to 9/22/85 Perforation Data ZONE TOP BTM SPF Condition Sterling 2,100' 2,140' 4,4 2-1/8" WL (8/21/89) / 4" H.S.C. (1/2" EH), (8/25/81) Contin enc Reperf Sterlin 2,162' 2,242' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8/25/81 Sterlin 2,256' 2,284' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8/25/81 Sterlin 2,313' 2,383' 4,4 2-1/8" WL 8/21/89 / 4" H.S.C. 1/2" EH , 8/25/81 Sterling +~~ ~-~rTc "p ~.... ,... _ _'_ . iF~'*, 7" ~ 2,461' TD =2,461' PBTD =2,413' Directional Data: Maximum hole angle = 0.5° at 2,450' WBD SRU 31 33WD Prooosed 7 06 10 docx Uodated by STP 7-06-10 RKB =184' KB I GL:186' AMSL KB-THF =19.02' Chevron Summary of Key Energy Rig #3 Specifics SRU 31-33WD Workover The SRU 31-33WD workover is to pull the existing completion, cleanout the fill in the 7", isolate the well and install a new wellhead and run a new completion. The rig specifics are for the planned rig up on this well and are likely to change from well to well. Proposed Configuration Rig Model The rig model is a Hopper Hydra-hoist, Back-model GXXTA. Drawworks The drawworks are GXXTA-MD 10x42; w/ Sand Drum 15,000 ft - 9/16" sand line. Derrick The derrick is a telescoping double, with 260,000 Ib capacity, 30" crown sheaves and McKissick 30" 150 ton 73A traveling block. Pipe Handling The pipe handling system is a HydraWalk-hydraulic catwalk, 38' long, 5' wide, 5' high. The base beam is internally guided and load bearing. The beam is load rated with 102' derrick and 10,000 of 2- 7/8" tubing to 58 mph winds. BOP Specifications Annular, 5M 7-1/16" Hydril GK ~ Single gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram (2-7/8", or 3-1/2" rams) Double gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram (2-7/8", or 3-1/2" rams) and blind ram Mud Cross, 5M, 7-1/16" BOP Diagram See attached. Accumulator 120 gallon KOOMEY Accumulator System. Includes 5 functions with manual bypass and remote panel. Eight 15 gallon accumulator bottles. 200 gallon hydraulic tank with air operated hydraulic pump. Pits The pit consists of a~200 bbl tank partitioned into three isolatable compartments. An optional shale shaker is also available that is a 3'x4' Jr. Standard-hydraulic driven. Pump The pump is a National JWS-400 7"x4.5" Triplex rated to 5,000 psi on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. ~ Key Energy Rig #3 Specs (SRU 31-33WD) rev0.doc 7/13/10 Chevron Kill Line Valves The kill line valves consist of 2 ea. manually operated, 2-1/16", 5M valves attached to the mud cross with co-flex hose with aUnibolt/Hub-flanged connectors. ~ Choke Line The choke line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. '" Choke Line Valves The choke line valves consist of 1 ea. manually operated, 2-1/16" 5M valve and 1 ea. remotely operated~CR-valve that is attached to the mud cross with co-flex hose with aUnibolt/Hub-flanged connect s_-~ Choke Manifold See attached. Choke Return Line/Diffuser Line The diffuser line will consist of 2", 5,000 psi hose with Unibolt connections. The line will run from the choke manifold to the diffuser tank. Diffuser Tank A diffuser tank will be placed adjacent to the mud pits with the capability of fluid transfer to the circulating system. Gas Detection There is a single gas LEL monitor and a single H2S monitor be placed at the work platform; and a single gas LEL monitor and a single H2S monitor at the shale shaker if used. PVT There is no PVT system for the circulation system on this workover rig, as is standard practice in this type of well service work. Key Energy Rig #3 Specs (SRU 31-33WD) rev0.doc 7/13/10 Chevron BOPE Diagram SRU 31-33WD Workover 7/06/2010 iular preventer, 7 1/16 5M Flan 3.08' I hatter chasovoy ~ v16 5 pipe Ram 9.00' 0 94~ stdd X 7 1~6 5M stdd I ~. 1.04' haffer chasovoy 7 1/16 5 Pipe Ram stdd X 7 1 5M stdd 2.2T Blind Ram O• Mud Cross, 7 1/16 5M FE X 7 1/16 5M FE w/ 2 1116 5M X 2 1/16 5M EFO Kill line 2 1/16 5M Choke line 2 1/16 5M 1.67' o 0 00 00 Unibolt HCR ~ Unibolt Ch Swanson River 2010 Choke Manifold 07/01/2010 Blooey Line To Gas Buster O ~ Unibolt Connection 0 ~• ~~ CheVrOn Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 Te1.907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com July 13, 2010 4•`j~~ Y ,~11i~. ~ ~ Zvi Commissioner Alaska Oil & Gas Conservation Commission eta ~ b 6aiwlt Gyro. Cat~t>NSSIfln 333 W. 7th Avenue AnC~toge Anchorage, Alaska 99501 Re: Swanson River Workover Program Variance Request for SRU 31-33WD Dear Commissioner, UOCC is preparing to perform well intervention work with a "well servicing unit" provided by Key Energy. Key Energy mobilized the workover unit here from the Rocky Mountain area in 2009. In 2009's program with this workover unit in Swanson River, we had requested variances to the regulations regarding the configuration of the choke and kill lines. The proposed configuration for this year's program meet the requirements and no ~ variance is being requested. The rig specifications and proposed BOPE and Choke manifold are attached for your review. We consider the application of this and all BOP configurations to be a well bore specific concern and do not intend or desire to consider this as an area wide or unilaterally applied configuration. UOCC appreciates your consideration of this proposal and looks forward to discussing any questions with the proposed configuration as needed. Attached is a brief description of the well to be worked on, and the proposed BOP configuration and schematic. Please let us know if we can provide any further information by contacting myself at 263- 7657 or Doug Nienhaus at 263-7840. Sincerely, ~. T ~-~- ~ , -.~ Timothy Brandenburg Drilling Manager Attachments: Summary of Workover Procedure, Actual Well Schematic, Proposed Well Schematic, Rig Specifications, BOP diagram, Choke diagram Union Oil Company of California / A Chevron Company MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation CommissIOn TO: Jim Regg P.I. Supervisor Ke11 JIJIOG DATE: Friday, September 01,2006 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 31-33WD SWANSON RIV UNIT 31-33WD \cao..\\~ FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv;1~ Comm Well Name: SWANSON RIV UNIT 31-33WD API Well Number 50-133-20336-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG06090 I 080409 Permit Number: 180-114-0 Inspection Date: 8/28/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 31-33WD Type Inj. N TVD 1917 IA 0 1580 1580 1580 I P.T. I 1801I40 TypeTest SPT Test psi 1500 OA I Interval REQVAR P/F P Tubing 330 360 350 350 I Notes No OA on this well. Well is temp. off injection. Tested well anyway and passed this test. /,' NON-CONFIDENTIAL ~çANNe[JJ SEP 0 8200B ....-.. Friday, September 01, 2006 Page I of I 31-33 WID Pre MIT . . «31-33 MIT 06.xls» «31-33 w-d chart.pdt» «WSR 31-33 MIT 06.doc» \r¿fr \ \ L\ Mr. Regg, We performed a pre MIT on disposal well 31-33 here at Swanson River. We would like to request an agency witness for the official test next week if possible (8/28 through 8/31). Thanks, Greg Merle SCANNED SEP 052005 Content-Description: 31-33 MIT 06.xls MIT Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: 31-33 w-d chart.pdf Content-Type: application/octet-stream Content-Encoding: base64 31-33 MIT Content-Description: WSR 31-33 MIT 06.doc Content-Type: application/msword Content-Encoding: base64 1 of 1 8/24/2006 3: 19 PM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: UNOCAL Swanson River Field/Swanson River Unit/31-33 WID Pad 08/21/06 Walgenbach Packer Depth Pretest Initial 15 Min. 30 Min. Weill 31-33 WID I Type Inj. I H20/Meth TVD I 1,917' Tubing 340 400 380 380 I ntervall 4 P.T.D.I 180-114 I Type test I p Test psil 1500 Casing 0 1610 1610 1610 P/FI P Notes: OA NA NA NA NA Weill I Type Inj. I I TVD I Tubing I ntervall P.T.D.I I Type test I I Test psi I Casing P/FI Notes: OA Weill I Type Inj. I TVD I Tubing Interval I P.T.D.I I Type test I I Test psi Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing I ntervall P.T.D.I I Type test I I Test psi Casing P/FI Notes: OA . Weill I Type Inj.1 TVD I Tubing Interval I P.T.D.I I Type test I Test psi I Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waist G=Gas I = Industrial Waistewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT Report Form BFL 9/1/05 31-33 MIT 06-1 .xls UeCAL ALASKA RESOUReS WELL SERVICE REPORT Date: A/?1/nR Well Number: ~1_~~ wIn Wireline Company: Location: SRF Work Being Done: Pre MIT AFE # I PO #: Present Operations: 5/1 Wireline Crew: UNOCAL Supervisor: Walgenbach Total Wireline Miles: Wireline Unit Number: Max Depth (KB): Zero Wireline at: Well KB: Minimum Tubina ID Max Tool Strina OD Time Operation Details T.P. P.C. 2:35 P 340 0 2:37 Start pumping diesel down the production casing ?·':tA ':tAn Rnn 2:39 390 1140 2:40 400 1610 2:55 380 1610 3:10 380 1610 3:25 380 1610 3:40 380 1610 End of test Bleed PIC to Zero 3:55 380 0 Work String Detail: R\S ,KJ, 10 stem, spangs Description of any None tools or debris left in the hole: Brief Summary of Swabbed 78 Bbls Total Work Completed: Ticket #: I I Day#: I Dailv Cost: I 1650.00 I Cumulative Cost: I Well Downtime Hr.n/A H2S PPM Total Hours Worked 11 Total Tool Cost200.00 Total Hour Cost 1450.00 I õ. I . £ Memo to the File 2/17/03 Unocal originally requested authorization to inject this treatment water in a class II disposal well. Although not allowed as a "class II fluid", AOGCC had proposed talking to EPA about handling this similarly to the G & I class V overlay. Before going to EPA we brought DEC into the loop and they discovered that Unocal's operation was being conducted without the necessary RCRA permit. AOGCC did nothing while DEC worked out the RCRA issues with Unocal. John Hammelman left a voice mail message in December advising me that they proceeded with a different plan for this water as a result of not hearing from us and no longer needed us to consider this option. It appears this case may have fallen through the cracks as a result of some miscommunication. SGANNEE JUL. 0 8 2003 , MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O. Taylor Chair THRU: Tom Maunder .~/'~/ Petroleum Engineer FROM: Lou Grimaldi Petroleum Inspector DATE: July 25, 2002 SUBJECT: Mechanical Integrity Tests Unocal Swanson River Field Swanson River Unit Soldotna Creek Unit NON- CONFIDENTIAL WellI 312-9 P.T.D.I 160-028 Notes: WellJ 314-4 P.T.D.J 160.021 Notes: Well J 243-4 P.T.D.J 161-029 Packer Depth Pretest Initial 15 Min. 30 Min. I Typelnj.I G I T.V.D. I 10150 I Tubingl' 950 I 9oo I~o I ~o I,ntervall 4 Type testI P I Testpsil 2538 I Casingl 1450I 2640 I 26201 26201 P/F I P' ': ITyPelnj.I 'G I T.V.D. 110191 I~u~,.~l 400 1370 I~,0 I ~,o I lntervall 4 Type testI P . I TestpsiI 2548 I'CasingI 1950I 2700I 2700I 2700I P/F I ,,P ITy,e,.j.I WD I T.V.D. I 2892 I TuU,ng IVacuumlVacuumlVacuumlVacuumllntervall 4 TypetestI P ITestpsil 1500 ICasingI 1000I 1640I !64o'I 164oI PIE. I ~P~ I Notes: Ori~linal PTD # WellI 31-33WD[Typelnj.I WD I T.V.D. 11917 I TubingI 900 I 900 I 900 I 900 I lntervall 4 P.T.D;I 180-114,Type.testI P. ITestPsil 1500 I Casingl 50 1163o1157o1152o1 P/F I'~P Notes: Type INJ.. Fluid Codes F = FRESH WATER INJ. G = GAS INJ.' S = SALT WATER INJ. N = NOT INJECTING WD = Water Disposal Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= 'Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V=. Required by Variance W= Test during Workover O= Other (describe in notes) I arrived at Swanson River Field and met with Ken Cassidy (Lead Operator), we reviewed the test procedures and tested the wells noted above. All wells tested "OK" with the exception of 31-33WD which had to be pressured up twice. This well was on injection when I arrived and the tubing and annulus were pulsing in concert due to the close proximity of the pump and small annulus area (5 1/2" inside 7"). This required the injection to be halted, the casing was pressured up and Was declining faster than allowed. We waited for approximately one hour for the well to stabilize and repressured the well;this time the decline was within allowable limits and passed the MIT. The pans of the field I was in were very cican and presentable, the roads were well maintained and travel was easy. M.I.T.'s performed: Four Attachments: None Number of Failures: None Total Time during tests: 5 hours cc: Doc Helton {Unocal Foreman) MIT report form 5/12/00 L.G. MIT Swanson River 07-25-02 LG.xls 8/26/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 UNOCAL ~ SWANSON RIVER FIELD -UNIT 051994 FEBRUARY 2002 Name of Operator Field and Pool Month and Year of Injection 1. 2. 3. 4. 5._o 6. TUBING PRESSURE CASING PRESSURE DAILY AVERAGE INJECTION TOTAL MONTHLY INJECTION WELL APl NUMBER ,,, FIELD~ DAYS 7. 8. 9. 10. 11. 12. t3. 14. & POOL ~ IN MAX AVERAGE MAX AVERAGE LIQUID GAS LIQUID GAS NO 50- CODE ~ OPER PSIG PSIG PSIG PSIG (BBL) (MCF) (BBL) (MCF) SRII 21-33WD 133-10162-00 5 772036 8 0 0 0 0 0 0 0 0 SRU 31-33WD 133-20336-00 5 772036 9 28 1,000 924 0 0 3,289 0 92,091 SRU 32-33WD 133-20337-00 5 772036 9 28 760 712 900 787 3,207 0 89,802 · I hereby certif, y~hat the foregoing is true and correct to the best of my knowledge 15. Signed . - ,- 'ri e z¢c . Date TOTAL Form 10-406 Rev 07/27/99 ~L;ANNE© ,~.AR i ! 2003 Submit in Duplicate RE: Follow-up to questions , , ..... Or'[ginal Message ..... From: Camille O. Taylor [mailto:Cammy Taylor@admin.state.ak.us] Sent: Tuesday, January 29, 2002 12:32 PM To: Hammelman, John C Subject: Re: Follow-up to questions John, I was in Juneau last week and have been trying to open your attachment since I got back. I just spoke with our IT folks and they tell me that it's a failure between our two e-mail systems to communicate. They suggested that you just paste the content of the document into the e-mail and that should work. Do you mind trying again? Thanks, Cammy "Hammelman, John C" wrote: Hi Cammy, Attached are responses to your questions. Please don't hesitate to call. Thanks, John Part 1.2 Type: Notepad File (application/ms-tnef) Encoding: base64 2 of 2 2/17/02 1:21 PM RE: Follow-up to questions Subject: RE: Follow-up to questions Date: Tue, 29 Jan 2002 13:46:29-0800 From: "Hammelman, John C" <jhammelman~unocal.com> To: '"Camille O. Taylor'" <Cammy_Taylor~,admin. state.ak.us> Please let me know what addition help I can provide. As mentioned below I'm available next week to meet with you. Thanks again. Below is a copy of the attachment that was sent. January 24, 2002 Dear Cammy, Below are responses to your questions. I'm available during the week of February 4th to meet with you if you think further discussion would help. I'd also invite Dave Brailey, who is our consultant helping with this project. Receiving this variance is very important, please let me know if I can help you further. 1. Is all of the Swanson River Oil Field inside the Kenai Wildlife Refuge boundaries? YES 2. What are the water quality criteria established in the Order By Consent for the P&S Yard? Amendment # 5 to the Order By Consent Mitigation Plan Swanson River OilField Kenai National Wildlife Refuge Remediation of contaminated groundwater shall continue until the groundwater meets the following criteria. Contaminant Toluene 0.50 Ethylbenzene Xylene 0.20 Cleanup Concentration (mg/L) 0.48 The concentrations listed above were developed through a risk assessment for the site which ADEC and USFWS have agreed to. I'd be. happy to send you a copy of the Order By Consent if you want one. 3. If the requested variance were approved, which Disposal Well would the groundwater be injected into? Both 3133 and 3233. Disposal wells ~ 3133 and # 3233 are tied together through a common header and are both currently being used for disposal of produced water. 4. Are the fluids [groundwater] considered non-hazardous under RCRA? Yes. The groundwater became contaminated when a tank containing xylene leaked. The xylene was an unused product, not spent material, and therefore does not meet the RCRA definition of a hazardous waste. 1 of 2 2/17/02 1:21 PM OCT, 29, 2001 12' i3PM UNOCAL OiL & GAS UNOCAL OIL & (;AS OPERATIONS 260 CAVIAR STREET KENAI, AK 99611 (907) 283-7505 (907) 283-5590 FAX NO, 9868 P, i IV£D 2001 FACSIMILE COVER SHEET TO: /"--'~? [~^,, DATE: /0/~ ? Id( COMPANY: FAX: 274. FROM: ~--] Urgent FYI PAGES: (Including Cover Sheet) Remarks: OCT, 29, 2001 12:13PM UNOCAL OIL g; GAS NO, 9868 RE: Request for Determination of Acceptability of Class II Injection of Contaminated Groundwater at Swanson River Field - Supplemental _Background Sometime prior to 1988, a large release of xylene occurred at the Swanson River Field Pipe & Supply (P&S) Yard. The xylcne was used to maintain oil wells, and was stored in a large (1,000 bbl) storage tank at the P&S Yard. Liquid xylene spread on the water table up to 700 feet downgradient, and surface water contamination was detected in the Swanson River approximately ~ mile from the site. A collection system was installed to intercept contaminated groundwater discharging into an adjacent wetland, which has operated continuously since 1991. After Unocal commenced operations in 1992, a number of remedial options were evaluated, including air sparging, bioventing, and above-ground biopiles. None of these were found to be particularly effective. In 1998, however, Unocal commenced large- scale excavation and landspreading, which was effective at reducing soil concentrations to levels protective of groundwater quality. Unocal successfully treated approximately 3 acres of contaminated soil, and reconfigured the site into a series of wetland ponds (Figure 1 Iai), Upon completion, however, additional contamination was found beneath the ponds, and in a 2-acre area around the periphery of the ponds. Although it was initially thought that the ponds would be effective at removing residual xylene, subsequent analyses showed that xylene is strongly adsorbed to soil, and only a small fraction is released into the groundwater. As a result, water-phase treatment (via either the wetland ponds or groundwater interception) is highly inefficient, and would take decades to complete. Furthermore, recent sampling shows that the existing groundwater interception system is not entirely effective, and xylene continues to leach into the downgradient wetland. Figure I. Existing and Proposed Site Configurations [al Existing (May 2001) [bi Proposed (Conceptual) OCT, 29, 2001 12' 14PiM UNOCAL OIL & GAS NO, 9868 P, Unocal is committed to an expedient site cleanup, and stopping the discharge of contaminated water into the downgradient wetland. To achieve these goals, the U.S. Fish and Wildlife Service (USFWS) and ADEC have tentatively approved wholesale excavation of the contaminated area, and ultimately the reconfiguration of the site into a more natural setting (e.g., Figure 1 [b]). During excavation, thc groundwater will exhibit xylene concentrations similar to the existing groundwater interception system (Figure 2). After removal of the contaminated soils, however, the groundwater should meet the criteria established in the Compliance Order by Consent and the Alaska groundwamr cleanup standards. Figure 2. Xylene Concentrations in the Groundwater Interception System, 80,000 60,000 0 ',1~ ~ 40,000 0 ~ 20,000 1~/6/01 Disposal Request During excavation and reconfiguration of thc site, Unocal requests permission to intercept the groundwater and dispose of it via injection in Swanson River Field' s Class II injection well. This will stop the discharge of contaminated water into 'the downgradient wetland, and greatly simplify the cleanup process by eliminating water storage and treatment problems during the remediation process. Underground injection is not likely to cause adverse effects on the local water balance, because the expected volume of groundwater to be intercepted is a small proportion of the flow through the surrounding wetland (Figure 1). Finally, underground injection would improve air ~/ quality and reduce greenhouse gas emissions by eliminating xylene discharge to the atmosphere from the air stripping treatment system now used. Due to the anticipated amount of soil excavation and treatment, the duration of the discharge could be up to four years. The flow rate of 8 gallons per minute (gpm) given in the August 24t~ letter did not include constmetion/remediation activities, but reflected the steady state pumping associated with summer operations. The maximum discharge should not exceed 40 gpm, and the average monthly discharge should be below 20 gpm, probably averaging much less than 20 gpm in the winter months. Timing Due to the lateness of the season, if our requested variance were approved, we would like to begin routing collected groundwater to the production system in early spring 2002. OCT, 29, 2001 i2: 14PM UNOCAL OIL g~ GAS . Ms, Cammy Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 W. Seventh Avenue Suite 100 Anchorage 99501 August 24, 2001 x0, 9868' P, 4 RE: Request for Determination of Acceptability of' Class II InjectiOn of Contaminated Groundwater at Swanson River Field Dear Ms. Taylor, Background Sometime prior to 1988, a release of new xylene product occurred at the Swanson River field P&S Yard from a bulk product storage tank. The actual quantity of xylene released is unknown, but the resulting contamination to the soils and groundwater beneath the site was extensive. In 1991 a groundwater collection system was installed down gradient of the spill site. The collection system was designed to intercept and collect the contaminated groundwater preventing it from reaching an adjacent down gradient wetland area, After the installation of the interception trench several remediation technologies were tested on the impacted soils and underlying groundwater. The technology chosen for treating the soils was land farming, Excavated material was land farmed for two years eventually leading to the construction of six treatment ponds that cascade down through the site. The logic was that after the soils were treated the ponds would polish off any residual xylene. Unfortunately this effort was not completely successful and we are still faced with managing the contaminated groundwater. The remediation of this site is continuing and we are working closely with the U.S. Fish and Wildlife Service and the Alaska Department of Environmental Conservation. Groundwater Treatment System Groundwater is collected in the interception system continuously, all year long. During past years, all the collected groundwater was pumped to an air-sparging tank, treated, and discharged onsite in a percolation cell. This past June we began bypassing the air- OCT, 29, 2001 12:14PMUNOCAL OIL &. GAS NO, 9868 P, 5 TO: Cammy Taylor -2- August 24. 200I AOGCC sparging tank, pumping the groundwater directly into the first of the six ponds through a series of spfinkletrs. Although this treatment method is working very well it will not work during the winter months. This winter the groundwater will again be treated through the air sparging system. Future Remediation As mentioned above, remediation of the site is continuing. Future plans will requke additional excavation and land farming of contaminated soil. The existing pond system will be destroyed in this process. Water management has been difficult in the past as all the water had to be managed through the treatment system while excavation and constructi°n of the ponds occurred, This includes both groundwater and storm water contacting the potentially xylene contaminated soil. On August 23, 2001, we met with the USF&WS and ADEC to discuss future plans. We will be gathering additional data from the site this fall and using that information to prepare a plan for the next step in the remediation effort, which we will begin next spring. Request The existing air sparging system is not capable of handling all of the groundWater at this time and is maintenance intensive due to iron fouling, which generates a waste which is typically slfiplved to an industrial waste landfill. The only way we can effectively' treat the water with the air sparging system is by reducing the flow rate at which we remove the contaminated groundwater from the ground, which compromises our ability to meet our environmental objectives. If we could ultimately pump this water into our Class II Injection Well we could easily manage all the water from the collection system. Likewise if we were allowed to dispose of the groundwater and storm water collected during construction activities this would make our remediation efforts more effective. If the contaminated groundwater were introduced into the oil/water separation equipment of our production system then any xylene that partitioned to the oil phase would be recovered for crude oil sales. Xylene is a normal constituent of crude oil. We respectfully request permission to process the contaminated groundwater and storm water collected from the P&S Yard remediation site through our production system with subsequent injection of the water phase into the Class 1I Injection Well. OCT, 29, 2001 12:i5PMUNOCAL OIL ~ GAS NO, 9868 TO: Cammy Taylor -3- August 24, 2001 AOOCC Groundwater Characteristics During the past few years the concentration of xylene in the groundwater collected in the interception system range between 20 and 60 mg/L (see attached lette~ to Alan Kukla). Water that is currently in the ponds is much cleaner and is non-detect in most of the ponds (see attached table). A graph and table are also attached which show groundwater flow rate and total gallons pumped this summer. The average flow rate over this past summer is 8 gpm. There will be periods of time when the flow rate is significantly higher. The addition of this water to the system will have no impact on operations. Thank you for your consideration of this request. If you have any questions or need any additional information, please contact John Hammelman at (907) 283-5507 or Laura Hammond at (907) 283-5508. Sincerely, John Hammelman Advising Environmental Scientist OCT, 29, 2001 12'15PM UNOCAL OIL & GAS ,,, NO, 9868 P, ? P&S Yard Pond Water Concentrations, Summer 2001 Pon~ Date ..B.~zene, Toluene,]'] Ethyl. Xylene..e~s_ Sample mg/L mglL. benzene mg/L 5/21/01 ND(0.001) .N.D(0.001) ND(0.001) ND(0,003) Pond6 6/14/01..~ ND(0.001) ND(0.0_0_'I~ ND(0.001) ND.~.003) ........ 6/26/01 ND.(0.001) ND(0,001). ND(0.001) ND(0,00_3_). 7/20/01 pending pending pen. ding pending 5/21/01 N__D.(O.001) ND(0,001) _ND(0.001) ND(0.00.~.)._ Pond5 6/14/01 _ND(0.001) ND(0.001)..,ND(0.001) ND(0.003.~.. 6/26/01 ND(0.001) ND(0.001) ..N..D(O.O01) ND(0.003) 7/20/01 pending pending pendin_g pending '" 5/21/01 ND(0.001) ND(0.001) ND.(,0_..001) 0.0036 ...... Pond.,.4,,.6/14/0'1 ND(0,00.!_)_ ND(0.001) ND(0,001)., .ND(0.003) 6/26/01 ND(0.001) ND(~._001) ND(0.001) ND(O.0.._0~)_ ~20/01 ..... pending pending . pending pending _ 5/21/01 ND(0.001) ND.(0._001) 0.0025 0.066 Pond 3 6/i'4/01 ND(0.001) ND(0,001.)..,..ND(0.001) ND(0,003)__ 6/26/~)¥-,. ND(0.001) ND(0.001) .,ND(0.001) ND(0.003)_ 7/2.0./01 pending pending pending Pending__ 5/21/01 ND(0,001) 0.02 0.13 0,64 Pond 2 ......... 6/14/01 ND(0.001) ND(0,0.01~)_. 0.0021 0,038 6/.2.6701__ ND(0.001) ND(0,001) ND0(,~.,~0!) 0.0069 7/20/01 pe nd,,!._n_gpending pending p e,n. di.n.,g.._ 5/2 /o ND(0,001).... ND(0,0,0, _)-ND(0.003)_ __ Pond 1 6/14/01 ND(0.002) ....... 0.0049 0.068 0.48 _..._.,~ 6/26/01 ND(0,002) . 0:0__0._29 0.022 0.17 7/20/01 pending pending pendi.,ng pending Swanson River P&S Yard Subject: Swanson River P&S Yard Date: Wed, 3 Oct 2001 08:53:52 -0800 From: "Seagren, Don" <Don_Seagren~envircon. state.ak.us> To: "'cammy_oechsli~admin. state.ak.us"' <cammy_oechsli~lmin. state.ak.us> My name is Don Seagren. I am the Contaminated Sites project manager for ADEC for the Swanson River P&S Yard site. I can be reached at 907-262-5210, ext 233; don_seagren@envircon.state.ak.us; ADEC, Kenai Area Office, 43335 Kalifornsky Beach Road, Suite 11, Soldotna, Alaska 99669; FAX 907-262-2294 In talking with John Hammelman, UNOCAL, this morning, he said that he had talked to you about their proposal for dealing with water at the Swanson River P&S Yard. If you hve any questions on the project or if I can be of any assistance to you, please contact me. I will be out of the office this morning and back in this afternoon. 1 of I 10/3/01 7:18 PM Unocal Alaska Resources Union Oil Company of California 260 Caviar Street Kenai, Alaska 99611 Telephone (907) 283-7505 UNOCAL ) RECEIVED AUG B 7 200 Alaska Oil & Gas Cons. Commission Anchorage Ms. Cammy Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 W. Seventh Avenue Suite 100 Anchorage 99501 August 24, 2001 Request for Determination of Acceptability of Class II Injection of Contaminated Groundwater at Swanson River Field Dear Ms. Taylor, Background Sometime prior to 1988, a release of new xylene product occurred at the Swanson River field P&S Yard from a bulk product storage tank. The actual quantity of xylene released is unknown, but the resulting contamination to the soils and groundwater beneath the site was extensive. In 1991 a groundwater collection system ~was installed down gradient of the spill site. The collection system was designed to intercept and collect the contaminated groundwater preventing it from reaching an adjacent down gradient wetland area. After the installation of the interception trench several remediation technologies were tested on the impacted soils and underlying groundwater. The technology chosen for treating the soils was land farming. Excavated material was land farmed for two years eventually leading to the construction of six treatment ponds that cascade down through the site. The logic was that after the soils were treated the ponds would polish off any residual xylene. Unfortunatel~¢ this effort was not completely successful and we are still faced with managing the contaminated groundwater. The remediation of this site is continuing and we are working closely with the. U.S. Fish and Wildlife Service and the Alaska Department of Environmental Conservation. Groundwater Treatment System Groundwater is collected in the interception system continuously, all year long. During past years, all the collected groundwater was pumped to an air-sparging tank, treated, and discharged onsite in a percolation cell. This past June we began byPassing the air- TO: Cammy Taylor -2- AOGCC August 24, 2001 sparging tank, pumping the groundwater directly into the first of the six ponds through a series of sprinklers. Although this treatment method is working very well it will not work during the winter months. This winter the groundwater will again be treated through the air sparging system. Future Remediation As mentioned above, remediation of the site is continuing. Future plans will require additional excavation and land farming of contaminated soil. The existing pond system will be destroyed in this process. Water management has been difficult in the past as all the water had to be managed through the treatment system while excavation and construction of the ponds occurred. This includes both groundwater and storm water contacting the potentially xylene contaminated soil. On August 23, 2001, we met with the USF&WS and ADEC to discuss future plans. We will be gathering additional data from the site this fall and using that information to prepare a plan for the next step in the remediation effort, which we will begin next spring. Request The existing air sparging system is not capable of handling all of the groundwater at this time and is maintenance intensive due to iron fouling, which generates a waste which is typically shipped to an industrial waste landfill. The only way we can effectively treat the water with the air sparging system is by reducing the flow rate at which we remove the contaminated groundwater from the ground, which compromises our ability to meet our environmental objectives. If we could ultimately pump this water into our Class II Injection Well we could easily manage all the water from the collection system. Likewise if we were allowed to dispose of the groundwater and storm water collected during construction activities this would make our remediation efforts more effective. If the contaminated groundwater were introduced into the oil/water separation equipment of our production system then any xylene that partitioned to the oil phase would be recovered for crude oil sales. Xylene is a normal constituent of crude oil. We respectfully request permission to process the contaminated groundwater and storm water collected from the P&S Yard remediation site through our production system with subsequent injection of the water phase into the Class II Injection Well. TO: Cammy Taylor -3- August 24, 2001 AOGCC Groundwater Characteristics During the past few years the concentration of xylene in the groundwater collected in the interception system range between 20 and 60 mg/L (see attached letter to Alan Kukla). Water that is currently in the ponds is much cleaner and is non-detect in most of the ponds (see attached table). A graph and table are also attached which show groundwater flow rate and total gallons pumped this summer. The average flow rate over this past summer is 8 gpm. There will be periods of time when the flow rate is significantly higher. The addition of this water to the system will have no impact on operations. Thank you for your consideration of this request. If you have any questions or need any additional information, please contact John Hammelman at (907) 283-5507 or Laura Hammond at (907) 283-5508. Sincerely, o~~ Hammelm a~'~n~ Advising Environmental Scientist Unocal Alaska Resources Union Oil Company of California 260 Caviar Street Kenai, Alaska 99611 Telephone (907) 283-7505 UNOCAL lune 30, 2001 Alan Kukla State of Alaska Department Environmental Conservation 555 Cordova Street- Anchorage, Alaska 99501 Re: P&S Yard Monitoring Report 110 - Permit No. 9623-DB002 Dear'Mr. Kukla: Attached is the May 2001 monthly monitoring report for the Swanson River Field P&S Yard groundwater remediation project. If you have any questions or need any additional infOrmation, please don't hesitate to contact me at (907) 283-5507. Sincerely, John Hammelman CERTIFIED MAIL cc: J. Frates, USFWS - Soldotna U. Kelmser, Chevron B. Fisk, USBLM D. Seagren, ADEC- Soldotna J. Stout,.USFWS, Anchorage File - SRF/Remediation/P&S Yard GW Monitoring U//,~;~/'2UUl U/' bB PAGE 02 987243375,:1 OILRISK CONSULTANTS i,~ OilRisk Consu 3527 North Point Drive Anchorage, Alaska 99515 · phone 907-248-0058 fax 907-2~3-3754 June 28, 2001 Unocal Corporation 260 Caviar Street Kenai, AK 99611-7769 Attn: Mr. John Hammelman SQbject: May, 2001. monitoring results for thc P & S Yard groundwater treatment system, ADEC Wastewater Disposal Permit No. 9623-DB002 .Dear John: . ~ This letter provides the May, 2001 monitoring results for the P & S Yard' groundwater, treatment syst~xn at Swanson River Field. Monthly maintenance and sampling was pcrfo.rmed on May 21 by David Brailey of OiRt,isk. Monitoring results are listed in Table 1 and are graphed below; hardeopies of the May, 200 ! laboratory.report are attached, 1~0,000 ---, '~ 120.~G0 .,,- ._q 1~ SO.GOO - ~ 4O,O~g Figure 1. lnfluent Monitoring Results (Recent) Figare 2. Influent Monitoring Results (L. ong Term) .~. 2oo,0oo -.~ ,~ ~ Total BI'EX concentradon ,- ~t.puinl running avamge ~ 1~o. o00 -- Ill $0.000 ~ 0 -- B072433754 OILRISK CONSULTANTS PAGE O3 Mr. John Harnrn¢lm~ June 28, 2001 Page 2 · Table 1. May, 2001 Monitoring Results P & S Yard Groundwater Treatment System Sample Date Benzene~ Toluene, Ethyl- Xylen~, Flow Rate, pg/L ~ benzene ~JL gpd -. ., Influ~nt 512 I101 ND(200) ND(200) 1,400 4,900 55 - ............... . April 27 to Effluent 5/21~01 ND(l) 3.30 48 190 May 21 Effluent limt (Permit N6. 5 5® 480 200 36,000 9623-DB002) Approximately 1,327 gallons of water were treated between April;' 27 and May 21, 2001, at an average daily flow rate of 55 g~tllons per. da), (gpd). Effluent BTEX concentrations were below the permit limits shown on Table 1. Thank you for the oppo. rtunity'to' provide these services. Please call should you have any questions. Sincerely, David E. Brailey · OilRisk Consultants · , Attachments: Analytica Alaska, Ino.. laboratory report da~ed June 14, 2001 16 E~ 12 0 6/9/01 6/16/01 6/23/01 6/30/01 7/7/01 7/14/01 - 1000000 7/21/01 7/28/01 8/4/01 - 80OOOO - 600000 "~ - 400000 "E 0 - 200000 0 8/11/01 Date 6/6/01 14:24 6/6/01 14:33 6/6/01 15:05 6/7/01 12:20 6/8/01 7:30 6/11/01 6:37 6/11/01 19:40 6/14/01 14:35 6/22/01 8:45 6/26/01 23:08 7/6/01 7:11 7/11/01 14:50 7/13/01 16:15 7/20/01 15:37 7/25/01 16:15 7/30/01 16:28 8/9/01 19:10 Datenum 37048.60 37048.61 37048.63 37049.51 37050.31 37053.28 37053.82 37056.61 37064.36 37068.96 37078.30 37083.62 37085.68 37092.65 37097.68 37102.69 37112.80 ., meter 330 455 975 11500 23000 75310 81920 118296 205730 249740 338270 390823 412367 486910 555780 641425 815450 flow rate 12.54 16.49 8.26 10.00 12.26 8.44 9.06 7.83 6.65 6.59 6.86 7.27 7.42 9.52 11.87 11.95 8.82 P&S Yard Pond Water Concentrations, Summer 2001 Pond Date Benzene, Toluene, Ethyl- , Xylenes, Sample mglL mg/L benzene m~llL 5/21/01 ND(0.001) ND(0.001) ND(0.001) ND(0.003) Pond6 6/14/01 ND(0.001) ND(0.001) ND(0.001) ND(0.003) 6/26/01 ND(0.001) ND(0.001) ND(0.001) ND(0.003) 7/20/01 pending pending pending pending 5/21/01 ND(0.001) ND(0.001) ND(0.001) ND(0.003) PondS 6/14/01 ND(0.001) ND(0.001) ND(0.001) ND(0.003) 6/26/01 ND(0.001) ND(0.001) ND(0.001) ND(0.003) 7/20/01 pending pending pending pending 5/21/01 ND(0.001) ND(0.001) ND(0.001) 0.0036 Pond4 6/14/01 ND(0.001) ND(0.001) ND(0.001) ND(0.003) 6/26/01 ND(0.001) ND(0.001) ND(0.001) ND(0.003) 7/20/01 pending pending pending pending 5/21/01 ND(0.001) ND(0.001) 0.0025 0.066 Pond 3 6/14/01 ND(0.001) ND(0.001) ND(0.001) ND(0.003) 6/26/01 ND(0.001) ND(0.001) ND(0.001) ND(0.003) 7/20/01 pending pending pending pending 5/21/01 ND(0.001) 0.02 0.13 0.64 Pond 2 6/14/01 ND(0.001) ND(0.001) 0.0021 0.038 6/26/01 ND(0.001) ND(0.001) ND(0.001) 0.0069 7/20/01 pending pending pending pending 5/21/01 ND(0.001) ND(0.001) ND(0.001) ND(0.003) Pond 1 6/14/01 ND(0.002) 0.0049 0.068 0.48 6/26/01 ND(0.002) 0.0029 0.022 0.17 7/20/01 pending pending pending pending MEMORANDUM STATE OF ALASKA TO' Well Files 31-33WD (80-114) and 32-33WD (80-115) FROM: Wendy Mahan DATE: April 13, 2000 RE: Unocal request to inject nonhazardous ethylene glycol waste into Class II well(s) at Swanson River Field I spoke to Laura Hammond on April 10th, 11th and 13th regarding Unocal's request to dispose of 6-10,000 gallons of ethylene glycol and flush water generated in the Swanson River Field (SRF). According to Laura, there are 12 1000 Btu heaters at well pads or tank settings at SRF. The heaters heat flow lines (oil out) or gas lift lines (gas down) to wellheads at oil producing wells. The heaters are natural gas fired and provide a heated ethylene glycol bath surrounding the flowlines. The glycol bath is necessary to reduce hydrate formation/freezing in the flowlines. The heater systems currently hold approximately 3,000 gallons of nonhazardous ethylene glycol. An additional 3-6,000 gallons of water must be used to flush the lines once the glycol is drained. Unocal originally planned to send the ethylene glycol portion of the waste to a commercial facility for recycling but was told that the glycol had degraded to the point that it was no longer usable. The only Class I disposal wells in Alaska are located on the North Slope. Transporting the waste for disposal on the North Slope would create an additional spill risk as well as unnecessary air pollution and fuel usage. Unocal could also. store the waste indefinitely and use it for make-up water when drilling activities resume. Storing the waste indefinitely while awaiting disposal also creates an additional spill risk. The Commission authorized the Class II injection of this "associated" waste as the most environmentally beneficial solution. I notified Laura of the Commissioners decision on April 13, 2000. [Fwd: ethylene glycol and flush water disposal] Subject: [Fwd: ethylene glycol and flush water disposal] Date: Thu, 13 Apr 2000 15:41:57-0800 From: Wendy Mahan <Wendy_Mahan~admin.state.ak.us> Organization: doa-aogcc To: Camille Oechsli <cammy_oechsli~admin.state.ak.us> Cammy, I accidentally left you off of this email. Subject: ethylene glycol and flush water disposal Date: Thu, 13 Apr 2000 15:40:45-0800 From: Wendy Mahan <Wendy_Mahan~admin.state.ak.us> Organization: doa-aogcc To: lhammond~unocal.com, Robert Christenson <robert_christenson~admin.state.ak.us>, Dan Seamount <dan_seamount~admin.state.ak.us> Laura, Unocal has requested to dispose of 6-10,000 gallons of ethylene glycol and flush water generated in the Swanson River Field (SRF) into two Class II disposal wells, 31-33WD and 32-33WD. According to my previous conversations with you, there are 12 1000 Btu heaters at well pads or tank settings at SRF. The heaters heat flow lines (oil out) or gas lift lines (gas down) to wellheads at oil producing wells. The heaters are natural gas fired and provide a heated ethylene glycol bath surrounding the flowlines. The glycol bath is necessary to reduce hydrate formation/freezing in the flowlines. The heater systems currently hold approximately 3,000 gallons of nonhazardous ethylene glycol. An additional 3-6,000 gallons of water will be necessary to flush the lines once the glycol is drained. Unocal originally planned to send the ethylene glycol portion of the waste to a commercial facility for recycling but was told that the glycol had degraded to the point that it was no longer usable. The only Class I disposal wells in Alaska are located on the North Slope. Transporting the waste for disposal on the North Slope would create an additional spill risk as well as unnecessary air pollution and fuel usage. Unocal could also store the waste indefinitely and use it for make-up water when drilling activities resume. Storing the waste indefinitely while awaiting disposal also creates an additional spill risk. The Commissioners discussed the situation and determined that Class II injection of this nonhazardous "associated" waste is the most environmentally beneficial solution. Please feel free to call me if you have any further questions, WendyMahan Natural Resource Manager 1 of 1 4/13/00 4:14 PM AOGCC Individual Well Geological Materials Inventory Page: Date: 11/19/98 PERMIT DATA T DATA PLUS RUN RECVD 80-114 PRESS/TEMP/GR L 9200-9480 1 10/07/94 10-407 R COMPLETION DATE / / / / / / DAILY WELL OPS R / / / TO / / / / / / Are dry ditch samples required? yes no And received? yes no Was the well cored? yes no Analysis & description received? yes no Are well tests required? yes no Received? yes no Well is in compliance Initial COMMENTS 100 101 320 321 370 371 380 381 425 426 429 430 2100.~ 2120z~ 2140 2182 'i~ 2256 2264 2284 23131,> 2383 T,D, 2461' 61 its. 2 7/8" 6.4# N-80 8rd EUE 1897. ,: Baker "F-I" Pahker w/Locator S.Assy 1917. SF~U 3l-3¥ W [ CASING &'TUBING DETAIL SECTION 33 T8N, R9W SM CIIEVRON USA INC. 9/23J. 85 GeoQuest $00 W. International Airporl Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 8975 Company: Alaska Oil & Gas Cons Comm , Attn: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 1017/94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 1-6 q ~'~--- I. '~ IPERF RECORD (9-20-94) 1 1 D.S. 2- lA ~ (~ --- ~ '~ 'STATIC PRESSURE SURVEY (9-19-94) 1 1 D.S. 3-31 ~, ~ .-- cjq.... BRIDGE PLUG RECORD (9-13-94) 1 1 D.S. 4-2'*~(~ - (:~ _~ TUBG CUTTER RECORD (9-13-94) 1 1 D.S. 5-4 "") ~ ~ ~ c/ STATIC PRESSURE SURVEY (9-19-94) 1 1 D.S. 5-19 ~-CJ .-----/~' STATIC PRESSURE SURVEY (9-20-94) 1 1 D.S. 7-24 ~ '~ '7' ~ ~ STATIC BHP SURVEY (9-19-94) 1 1 D.S. 9-26 _~ L! _.- 3"'7 POGLM SETTING RECORD (9-11-94) I 1 D.S. 13-13 ~ '2.. '"! '",t ~" LEAK DETECTION (9-20-94) 1 1 D.S; 15-37 ~ el/---- '7~' STATIC BHP SURVEY/PERF RECORD (9-15-94) I 1 D.S. 16-5 ~ I"' ~. ~ STATIC; BHP SURVEY/IN,JEC PROFILE (9-16-94) 1 1 D.S. 16-14 ~ [ .--- ~' 'Z_._- PROD PROFILE (9-8-94) 1 1 D.S. 16-22 ~-'- ,.,,~i PERF RECORD (9-11-94) 1 1 . I SI DATE: Pleas~sign and return one copy of this transmi;al to Sherrle at the above address. Thank you.' Unocal North Arnerical Oil & Gas Division ~. Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL May 5, 1994 Alaska Region Commissioner Russ Douglas Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak. 99501 Dear Commissioner Douglas: Application for Sundry Approvals Mechanical Integrity Tests Swanson River Field Union Oil Company of California (dba Unocal) requests approval to perform the aLi. ac;-,ed M~u;,~,,iu~; ;,~;.~g~ii.y Tu~i.~ u~ i.i~u i'uiiuwi~ wuii~ ir~ Li~ Swar]~un Rive[' Fieid: ~;C;, ~.~ SRU 31-33WD u.'~-- :.~-cf SCU 43-4MD t.,.~' ~ '- 2. \ SCU 323'-9 The last well listed above, SCU 314-4, was scheduled for an M.I.T. in 1993, but due to tubing to casing communication, this well could not be tested in 1993. The tubing was pulled from this well and replaced in December, 1993 and the well is now ready to be tested. The above proposed M.I.T. tests are being done to satisfy the requirement to test 25% of our Class II Injection wells per year. If you have any questions, please contact me at 263-7816. Very truly yours, Petroleum Engineer R£C£1x/ED M~X¥ ] 2 1994 Gas cons. Commission Anchorage STATE OF ALASKA ~ ALASH'." 3IL AND GAS CONSERVATION C~' MISSION ~'~ APPLICATION FOR SUNDRY APPROVALS i. Type of request: Abandon __ Suspend __ Operations shutdown __ Re-enter suspended well__ Alter casing__ Repair well __ Plugging __ '13me extension Change approved program __ Pull tubing Variance __ Pedorate OtherX (MIT) 2. Name of Operat= 5. Ty~ of Well: 6. Datum elevation (DF or KB) Unocal ~__ KB: 165' Exploratory ~ feet 3. Address StmUgraphic __ 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska 99519-6247 sewice X_ Swanson River Unit 4. Location of well at surface 8. Well number 961' FNL, 1386' FEL, Sec. 33, T8N, R9W, SM SRU 31-33WD At top of productive interval 9. Permit number Straight hole 80-0114-0 At effective depth 10. APl number 50-133-20336-00 At total depth 11. Field/Pool Swanson River/Sterling 12. Present well condition summary Total depth: measured 2461' feet Plugs (measured) true vertical 2461' feet Effective depth: measured 2413' feet Junk (measured) true vertical 2413 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 10-3/4' Driven 80' 80' Surface Intermediate Production 2461' 7' 800 sx 2461' 2461' Liner 2015' 5-1/2' 100 sx 2015' 2015' Perforation depth: measured 2100-2140, '2162-2242, 2256-2284, 2313-2383 true vertical 2100-2140, 2162-2242, 2256-2284, 2313-2383 R E C E IV E D Tubing (size, grade, and measured depth) 2-7/8', EUE, 8rd @ 1917' MAY I 2 1994 Packers and SSSV (type and measured depth) Model F1 pkr. @ 1917' Alaska i~AI & Gas Cons. Commission 13. Attachments Description summary of proPOsal __ Detailed operations programX__ BOP -~J~l~'~'' 14. £stimated date for commencing operation ! 5. Status of well classif',:ation as: 5/94 .... 16. If proposal was verbally approved Oil__ Gas Name of approver Date approved Service Water disPOsal _ "i7. I hereby c th t the or. ego,[ng/,is tr~ correct to t~e best of my knowledge. ~ [ j FOR COMMISSION USE ONLY Conditions~f approval: Notify Commission so representative may witness I Approval No. Plug Integrity ~ BOP Test Location clearance Mechanical Integrity Test.z/ Subsequent form required 10- Original Signed By .. .David W. Johnston Approved by the order of the ~;omm~ss~on Commissioner Date ~--///'~/'"~ Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRIPUCATE PC & SC Loading and PC pressure Test SRU 31-33 WD Objective: To load the PC and SC and verify mechanical integrity on the PC. Well Data; Tubing: 2-7/8" to 1917' MD PC: 5-1/2" 17# & 20g N-80 to 2015' MD SC: 10-3/4" to 80' MD Top packer depth: 1917' MD Capacities: Tbg. x PC = .0152 Bbls./Ft. Current Pressures: Tbg. = 1080 psi, PC = 12 psi Procedure: Load PC aru~ SC II Install a two-pen recorder on the well to monitor the SC and PC pressures. . Shoot fluid levels on the PC. (Skip to step//9 if no load is needed on the PC). Calculate needed load volume to fill PC. Assure that this fluid is on location for load. 3. Monitor tubing, PC and SC pressures throughout the job. 4. Hold safety meeting. 5. RU choke and gas buster to PC as needed. 6. Blow down PC pressure without allowing fluid production. 7. Hook up pump truck to PC and pressure test lines to 4500 psi. . Load PC with lease water containing .25 % WT676 corrosion inhibitor finishing with a 5 Bbl. crude cap. Do not exceed 3000 psi during pump- in. (Several 1,000 psi blowdownfloads may be required). NOTE: Contact the AOGCC (279-1433) and BLM (271-4417, 248-3010) at least 24 hours prior to testing the PC so that an agency wimess can verify the test results. 9. Pressure up PC to 500 psi over current pressure (1500 psi maximum). Hold for five minutes (observing tubing, PC and SC pressures). RECEIV£D M~Y I 2 1994 Gas Cons. CommJssJo[~ Anchorage 10. 11. 12. If less that 50 psi is lost in five minutes, increase pressure by 500 psi. Hold for five minutes. Repeat step #10 until 1500 psi is reached. Hold pressure for 30 minutes, noting initial and final pressures on all strings. Rig down. RECEIVED M~Y 1 2 1994- Gas Cons. Commission Anchorage &~ r 410' J' f~. · ' ~" #/F ($Q01 I RECEIVED MAY 1 2 1994 AJ~ska Oil & Gas Cons. Commissio~ ~i Anchorage · -__ ~.'!2; -=' ,,ooc. L ,. ~ t.[, ,., ~, / ~. . t,,, /:! I z ! J ~b~,** eS , · C~ASING & TUBING OETAI~ S[CTION 33 T. IN~ R. ow. Su ARCO ALASKA INC. Cook Inlet Engineering #556 TRANSMISSION TO: Blair Wondzell COMPANY: AOGCC DATE: 1/2/92 FROM: Victoria Ferguson COMPANY: ARCO Alaska, Inc WELL NAME: Listed below Transmitted herewith are the following Blue Sepia Sepia Fape & Line Folded Rolled M~,lar listing Temparature Log - SRU 31-33WD 1 1 Perf Record - SCU 12A-3 1 1 , ,, Receipt Acknowledgement: ~ ~_ ~ a~. a~ef~n~a~., t~ Retum reciept to ARCO ALASKA, Inc. ATrN: Judy Boegler AT~I~:.~E IV ~ D Post Office Box 100360 Anchorage, AK 99510-036~f5, N-- - 6 ~,laska Oil & Gas Cons. CommissiOn Anchorage Date: ARCO Alaska, Inc.~ ~. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures August 9, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Results of Pump-In Temperature Survey of SRU 31-33._~_~~ Swanson River Field Dear Mr. Chatterton: This is to submit the results of the pump-in temperature survey (PITS) that was performed on SRU 31-33WD on May 14, 1989. The test was done to prove that current injection practices (over parting pressure) are not resulting in fractures that extend through confining zones enabling disposal water injectant to enter any fresh water strata. The pump-in temperature survey was obtained in accordance with the submitted sundry, as previously approved by your office. The results prove that this well is injecting up to -1970' MD,. which is 270' below the legal injection cut-off depth of 1700' (see attached Survey). If you have any questions concerning this matter, please contact Stacy Strickland at 263-4914. Sincerely, T. S. McCorkle TSM:SLS:ch:0004 Attachment Ar/cbora, qe' °rnrn~ss~on cc: S.W. Ohnimus A. R. Kukla UNOCAL Corporation Marathon Oil Company ARCO Alaska, Inc. is a Subsidiary of AllanticRIchfieldCompany AR35--.4~'! 79 , 1 STATE OF ALASKA '~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLI TION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-emer suspended well __ Pump - i n Alter casing __ Repair we!l __ Plugging __ Time extension __ Stimulate __ Change approved program ~ Pull tubing __ Variance __ Perforate ~ Other X~ Temp. s u r vey 2. Name of Ooerator I 5. Type of Well: ARCO Alaska I nc i Development__ ' · Exploratory __ 3. AaCress Stratigraphic_ P. 0. Box 100360 Anchorage, AK 99510 Serv,ce X 4. Locatton of well at surface 961' FNL, 1386' FEL, Sec. 33, T8N, Rgw At top of productive ~nterval Straight Hole At effective depth At total depth 6. Datum elevation (DF or KB) 165' GL feet 7. Unit or Property name Swanson River' Un il- 8. Well number SRU 31-33WD 9. Permit number 10. APl number 50-- 133-20336-00 11. Field/Pool Swanson River/Sterling 12. Present well condition summary Total depth: measured true vertical 2461 ' feet Plugs (measured) 2461 ' feet Effective depth: measured true vertical Casing Conductor ~)~X Production Liner Perforation depth: fe~ Junk(measured) 2413' feet 2413' Length Size Cemented Measured depth 80' 10-3/4" driven in 0-80' 2461' 7" 800 sx 0-2461' 2015' 5-1/2" 100 sx 0-2015' measured 2100-2120'; 2140-2162'; 2182-2256'; 2264-2284'; 231~-2383' truevertical 2100-2120'; 2140-2162'; 2182-2256'; 2264-2284'; 2313-2353' Tubing (size, grade, and measured depth) 2-7/8" EtJE litRD e 1917' MD Packers and SSSV (type and measured depth) Model F-1 packer ¢ 1917~ MD True vertical depth 0-80' 0-2461 ' 0-2015' 13. Attachments Description summary of proposal Detailed operations program X E i V ED 14. Estimated date for commencing operation May, 1989 16. If proposal was verbally approved' Name of approver Date approved 15. Status of well classification as: Oil __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. JAN - 2 Gas __ Suspended __ Alaska 0il & Gas Cons. ComB' Water D i sposa I. ;Anch0ra0e Signed ,~,/J~¢'.~,~/~-~'~- TitleCook Inlet Engineering rvlanager Date _,~/~q FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. Plug integrity ~ BOP Test ~ Location clearance __ I Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Pump-In-Temperature-Survey SRU 31-33WD SR 40 Objective: To determine the interval(s) receiving disposal water in this well while injection is maintained over parting pressure. Well Data: Completion Perforations: Last PBTD tag: Current Pressures: Est. Parting Pres.: 2 7/8" EUE 8RD tbg Set @ 1917'MD 206' Total; Top Most @ 2100' MD, bottom @ 2383' MD 2180' WLM on 4/7/89 (2.2" gauge ring) =730 psi tbg. inj. pres.; PC = 0 psi 590 psi surface injection pressure Procedure: 1. SI well for at least 24 hours. t Hold safety meeting. Assure that at least 300 Bbls of heated (150°F+) lease water is on location. (A steamer can be used to heat the fluid). 3. RU E-line. Pressure test lubricator to 1000 psi. . RIH with CCL/temp tools (CCL on top). Record temperatures from 1200' MD to PBTD. Do not exceed a 30 fpm line speed below 1200' MD. 5. Tie-in with tbg tail. t Re-log bottom 200' at 30 fpm to verify temp tool repeatability (down nm). Leave tool on bottom. , RU pump truck and tie into tbg. Pressure test lines to 1000 psi. Pump at least 300 Bbls of heated lease water (150°F+) at over 700 psi surface injection pres. SI well. 8. POOH to 1200' MD at 30 fpm. 9. Log down to PBTD at 30 fpm recording temperature data. I0. Repeat steps 8 and 9, as needed, to determine the intervals which receive water injection (these areas will be warmer than surrounding intervals). A minimum of 3 hourly passes will be required. 11. POOH. RDMO. 12. Return well to injection. ARCO Alasl<~ Inc. Is · lui~idlar/o~ Atlantic Richfield Compmny AR3B.6(X)I-A lJ~w 111' 410' 4- ~" ./~ . ---- IOl~' / g I q- I~t0 / I, · % ~ , . ttJJ ' ~ mdd~:bho T.O. 2461' SRU ' $1 · 33 CASING & TUBING 0ET~It. SECTION 35 T.I#., R. gW. SM E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Maste~ Valves Wellhead ARCO Alaska, Inc. ~ Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering December 19, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Results of Pump in Temperature Survey on S..RU 31-33WD. __ Dear Mr. Smith: ARCO has recently completed a pump-in temperature on the Swanson River water disposal well SRU 31-33WD. This work was done as part of our ongoing program to ensure that our disposal wells are being operated in compliance with the Area Injection Order # 13. Included for your files are copies of the temperature logs along with the daily well service reports for the work. The data shows that all of the injected fluids are remaining within the perforated interval between 2,100' and 2,383'. If you have any questions please contact Jim Zernell at 263-4107. Sincerely, ~ ' ,/.? \ , ,.L CoWhnn RECeiVED JCW:JTZ:czm:0024 Attachment CC' Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation ,~ft, laska Oil a aaa Ooas. Com~r~issio~ Anch0ra~e ARCO Aleska, Inc. Is a Subsidiary of Atlantic Richfield Company WELL Sul~ldl~'y of Atlantic RIChfield SWANSON RIVER IFliLD · DISTRICT · 8TAT! DUCTION P,~2/~ WELL SERVICE REPORT i,,i A.nchora2e · CHECK THIS BLOCK IF SUMMARY CONTINUID ON BACK , ~~~.,,~,.. ,IO~ON Af~~~ ' - - , ' · ~L~ / ~d~ ~~ ' ! ,_ _ ,- ' - ~ -- -' -, ' [ I , ._ _. . _ _ _ ~_ ~,,,~. ~,-.~ ~~p/C:~L · 11-16-1991 14: O? 90? 283 1~)30 SWANSON RIVER PRODUCTION P, ~5 , i. " DISCFiiPTION DAILY AccuM. TOTAL i ~ i ii i ~.M ff..,O .. - ......... '~1 'u~ __-. I. ii I II DMF_=_-=! ....... , ......... ,m . · _m I I I I HA_LU.IUII~ON i ii ·ijll ii i~ -- AlalG'TI{~ C~IL TUnINg3 .............. a,/'t.M , It, d, HUGH~" '. ...... ~1~_-'! ..... ,IL,II,m,m ~ · ~_-,ent. !_-!on , , _ i1.. . AF~ , , ........ I II I I I-- ~ i i ,I · I I I II I I I I I . I I ~ I iii i II I Jl II i I II _ I IL __. ,.- i ii I I~II J i SlIT FlIIulls - 31-13 WD 11111i/I1 II I0000 Iit° iii' tdOt,dV.~ q-zl-rJ' SRU ' 31 · 33 CASING'& TUBING O[TAII. S[C:TION $$ T. IN., R.~W. ii ii i i LL/BURTON TEMPERATURE LOG I COMPANY ....... l~ ~8sur~ Fr~ ~// __ Drdli~ ~asurN Fr~ Depth--L~ger ~ ....... ~hnd ~ NaCI .. ...... ~ ............................ ~ .... ~._~ .................. ~qu,~ _,. t~,~ ............. ~/y__/j ~.~'~ ............ ~UN B~E~LE ~C~O CAS~ & TUBI~ '.~-"~ ..... .,z' ~.~ ~ ..... ~ ...... Xm ~,? ~, ........... ~'~ ~ ~~ .............. I I : I U U ! BI I I Ill I I · I iI i I I !~i I I [ Ill I I Ill [ Il II I Ill I I I ltl ! I ! I11 i [ l'l I I IH I I ~ , - ! Ill i I I , Ill I I ~1~ l ~ IllIllll I illIII11 ! ' iiiI11 III I i iiiIulii I ! ! Il I11 I11 l I 1 Ii [II l!] II I I ~IIl I11 !I ! mil!lililI1 il IIllilII i I I [ lilli i t iI ! lllll I __~_ Illll I I I I! i11111 I I ' ~- '' I! I III[Iii I i Ii I t11111! I .~ ' Ill I [I1 ! 11 IIi111i1 ! ~ I1 IIII1[!I ~ .~ ! ~ I III ltl il il I I Ill i I1 Il ti I i ill i i, Iltl [ I 11 ! !1 Illl ' I i 111 I I Iil I , [ ili'l I III l I Ill. ! I I II ! I Ill I ! i Il i!l\~ 'l Ill ! I iii .I ',ii I Ill ! i I1 I , I Ill i ! I I I Ill ! I 11! I I !11 I I1!!1 ~ ; '.\ I Iii I IlIII [ i ~ ' I III ! I~J lib I I Iii ! 1111111 i, ! I il! II 111! ! I ill ! Illlll ! I i IIi IlllllI 'ii' I I I III I llllll , ! I I ! I Iilll ] I I t i IIi1111 I ! -- I I !\i II1 t I I i'I I ![,1~11 I Ii k IIl!B Il :1 ~.,',,:~,,,, I I.~i,.,.-i'~. III I!I't~' i I I! I '4il'dlili ......i I II I,!t,,11 -J' -T-r--~iTqT--I~T¥"" '~::-i:":I I . .- I ,~ L L .Il J__l,~J It. Il ! ,_ _ llt J I~i I i I ! ! lll X'~..'" i ' I I I I I m-ii~imm]mm .l[ni.nn ..... n ~0 m m~{ ,..- _ SRU 31-33WD. _ - Temperature Log - ~- 11 ~,,- '-~ ~ ~- 3AEING ..1~ ?" 't mmm~mmmmm -20. lO0 200 300 400 500 60O 7OO 8OO 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2OOO 2100 GR 1991 (GAPI) ARCO ALASKA INC., SRU 21-3,3 WD, SR 711, JUNE 23,1991 ( 74656 ) TIME LAPSE TEMPERATURE TIME LAPSE PRESSURE 50 (DEGF) 100 0.0 (PSI) 1500 p,~r-~$ '7_(z~ '- ~e ' . ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering October 17, 1990 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached are Sundry Notices and Well Service Reports which document the production casing pressure tests performed on SCU 323-9, SCU 43-4WD and SRU 31-33WD. The wells were tested in accordance with Rule 6 of the AOGCC Area Injection Order No. 13. All wells held their required test pressure (within 10%) for 30 minutes. These pressure tests serve to partially satisfy the requirement to test 25 percent of our Class II wells per year. Please contact Carol Baker at 263-4643 if you have any questions concerning this matter. Sincerely, T. Wellman TW:JKW:ch:0001 Attachment cc: Mr. A. R. Kukla Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ~" " ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS I. Type of Request: Operation Shutdown~ Stimulate Plugging. Perforate Pull tubing Alter casing Repair well Pull tubing Other MIT 2. Name of Operator ARCO Alaska. I nE, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 961' FNL, 1386' FEL, Sec. 33, T8N, R9W, SM At top of productive interval Straight Hole At effective depth At total depth 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 165' KB 7. Unit or Property name Swanson River Unit 8. Well number SRU 31-33 WI) 9. Permit number/approval number 10. APl number 50- 133-20336-00 11. Field/Pool Swanson River-Sterlinq feet 12. Present well condition summary Total Depth: measured true vertical 2461' feet Plugs (measured) 2461' feet Effective depth: measured 2413' feet Junk (measured) true vertical 2413' feet Casing Length Size Cemented Measured depth Structural Conductor 80' 10-3/4" Driven 0-80' Surface Intermediate Production 2450' 7" 800 sx 0-2450' Liner 2015' 5- 1/2" 1 O0 SX 0-2015' Perforation depth: measured 2100'-2140' MD; 2162'-2242' MD; 2256-2284' MD; 2313'-2383' MD true vertical 2100'-2140' TVD; 2162'-2242' TVD; 2256-2284' TVD; 2313'-2383' TVD Tubing (size, grade, and measured depth) 2-7/8", EUE 8rd @1917' MD Packers and SSSV (type and measured depth) Model F-1 Packer @ 1917' MD True vertical depth 0-80' 0-2450' 0-2015' R'ECEi, VE:D 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A CK .T 2 1990 Gas Cons..Qlalllllss[gll ' cfiorage 14. Prior to well operation Subsequent to operation ReDresentative Daily Average Production or Injection Dat~ Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 5506 0 0 0 5506 0 Tubing Pressure 776 776 15. Attachments Copies of Logs and Surveys run~ Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Wtr. Di SDOSal 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 06/15/88 Title Cook Inlet Regional Engineer Date I~-I?'~ SUBMIT IN DUPLICATE ARCO Alaska, Inc(. .~ ~i:, ~uu/l~tlty of A~Iir~IG RIc.,hlflld ComO~rtv WELL [~-~ I F~LD- DISTRICT-STAT~ CONTRACTOR - - .--~tf- l~_~s~_ ! IOPe~T~ON AT REPORT TIME EMA;K~ ' "' ' WELL SERVICE REPORT l~b _m. 0 I:~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Wlltherl Tlmp'Report 'F [ Chill Flclor 1 VIIIblIItY'F mlle. Wind Vel. .. TYPE(IF PKR ~ TVO FI.Uti) ND ALASKA OIt MEa4AN ICAL IN~.I T*Y ...... ~ I NG TI~ ~ TBG T Ill~ TiME -T I1~ START $ I ZF./NT/(31/ii~ $1Z~ l'Es'r cs~ ~ TBG ~ TINE ~ PRESS CSG Iq~7 go~ ~o 800,,,...,"° /~ o /~ o /~:~ *TI~II~ ,tNG INJL'CTI,~I, KUIO: p - PRGCIJC~ IATER IKJ S - SIKJ IATER INJ M - NISCleU~ IKJ~CTI[I( I - C.O~ (rev 05/10/90] NEEUL.M~ FI. UIO: CR;~IEXT: DIESEl. i iii SALT WiTER - i i DRILLJN~ ~ · · TEST: · AOGCC Itl~ ARCO Alaska, Inc.' ~,~ PoSt Office Box[ :60 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering June 13, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: ARCO Alaska, Inc. requests approval to perform the attached mechanical integrity tests on SCU 323-9, SCU 243-4MD, and SRU 31-33WD. This testing is designed to demonstrate tubing and production casing integrity in accordance with the AOGCC Injection Order No. 13, Rule 6. It is being done to satisfy the requirement to test 25% of our Class II wells per year. Plans are to perform the MIT's as soon as possible as the testing deadline for the 1989-90 program is June 30, 1990. Please contact Carol Baker at 263-4643 if you have any questions concerning this matter. Sincerely, T. Wellman Regional Engineer TW:CMB:ch:0030 Attachment cc: A.R. Kulda S. W. Ohnimus Marathon Oil Company UNOCAL Corporation REEEIVED JUN 1 9 1990 Alaska Oil & Gas Cons. C0mmiss~u, Anchorage ARCO ~ Inc. Is a Sub.diary of Atlantic Rlchfleid Company STATE OF ALASKA 0 ALASKA OIL AND ~ ~RVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other X MIT 2. Name of Operator ARCO Alaska. Int, 3. Address P. O. BOX 100360, Anchorage, AK 4. Location of well at surface 99510 5. Type of Well: Development Exploratory Stratigraphic Service 961' FNL, 1386' FEL, SEC. 33, T8N, R9W, SM At top of productive interval Straight Hole At effective depth At total depth 12. Present well condition summary 6. Datum elevation (DF or KB) 165' KB 7. Unit or Property name Swanson River Unit 8. Well number SRU 31-33 U/O 9. Permit number 10, APl number 5o-133-20336-00 11, Field/Pool Swan ~1 ~er~$~ilip, gr.~ I~E~EI VEIJ feet Total Depth: Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 2461' feet Plugs (measured) true vertical 2461' feet measured 2413' feet Junk (measured) true vertical 2413' feet Length Size Cemented 80' 1 0-3/4" Driven J UN 1 9 1990 Alaska 0il & Gas Cons. Commission Measured depthAnCr~L~a{]~lrtical depth O-8O' O-80' 2461' 7" 800 SX 0-2461' 0-2461' 201 5' 5- 1/2" 100SX 0-2015' 0-201 5' measured 2100'-2140' MD; 2162'-2242' MD; 2256'-2284' MD; 2313'-2383' MD true vertical 2100'-2140' TVD; 2162'-2242' TVD; 2256'-2284' TVD; 2313'-2383' TVD Tubing (size, grade, and measured depth 2-7/8", EUE 8rd @ 1917' MD Packers and SSSV (type and measured depth) Model F-1 Packer @ 1917" MD 13. Attachments Description summary of proposal _ Detailed operation program BOP sketch 14. Estimated date for commencing operation 15. June 1990 Oil Gas 16. If proposal was verbally approvedD Name of approver Date approved Service Water 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Status of well classification as: m Suspended Title Cook Inlet Regional Engr. FOR CC~MISSION USE ONLY Disposal Date /////~/'~' o Conditions of approval: Notify Commission so representative may witness Plug integrity m I~O/P Test m Location clearance m Mechanical Integrity Test'/~ Subsequent form require 10-"~ Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Approved Copy IApproval No. SUBMIT IN'TRI'PLICATE PC & SC Loading and PC Pressure Test SRU 31-33WD, SR 162 Objective: Well Data: To load the PC and verify mechanical integrity on the PC. PC: SC: Top pkr. depth: Capacities: Current Pressures: Procedure: 2-7/8" EUE tbg to 1917' MD 5-1/2" N-80; 17 & 20# to 2015' MD 10-3/4" to 80' MD 1917' MD Tbg x PC = .0152 Bbls/ft. Tbg=800psi; PC=0psi NOTE: 1. Install a two-pen recorder on the well to monitor the SC and PC pressures. 2. Shoot fluid level on the PC. (Skip to step #9 ff no load is needed on the PC). Calculate needed load volume to fill PC. Assure that this fluid is on location for load. 3. Monitor tbg., PC and SC pressures throughout the Job. 4. Hold safety meeting. 5. RU choke and gas buster to PC, as needed. 6. Blow down PC pressure without allowing fluid production. 7. Hook up pump truck to PC and pressure test lines to 4500 psi. 8. Load PC with lease water containing .25% WT676 corrosion inhibitor finishing with a 5 Bbl crude cap. Do not exceed 3000 psi during pump-in. (Several 1,000 psi blowdown/loads may be required). Contact the AOGCC (279-1433) and BLM (267-1243) at least 24 hours prior to testing the PC so that an agency witness can verify the test results. PC Pressure Test 9. Pressure up PC to 500 psi over current pressure (1500 psi maximum). Hold for five minutes (oi~~]i~tD~.~PC and SC pressures). JUN 1 9 1990 Alaska Oil & Gas Cons. Commission Anchorage PC & SC Loading and PC Pressure Test SRU 31-33WD, SR 162 Page Two 10. 11. 12. If less than 50 psi is lost in five minutes, increase pressure by 500 psi. Hold for five minutes. Repeat step #10 until 1500 psi is reached. Hold pressure for 30 minutes, noting initial and final pressures on all strings. RDMO. .,..~ /c. . Ala~l~a.Oil& Gas Cons. Commission Anchorage 11o· ij~e' 380' 188' dS' 416' 411' J. ~,. 4. ~" )fdr C soo) RECEIVED Alaska 0il & Gas Cons, Commission Anchorage SRU ' :51 - 33 W.*D. CASING & TUBING OETAIE SECTION 33 T. SNq R. gw. ARCO Alaska, Inc. {~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures September 13, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Results of Re-perforation SRU 31-33WD Swanson River Field Dear Mr. Chatterton: This is to submit the results of the re-perforation of SRU 31- 33WD that was performed on August 21, 1989. If you have any questions concerning this matter, please contact Stacy Strickland at 263-4914. Sincerely, T. S. McCorkle TSM:SLS:ch:0008 Attachment ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 STATE OF ALASKA .. AL( .A OIL AND GAS CONSERVATION COMMli REPORT OF SUNDRY WELL OPE TIONS 1. Operations performed: Operation shutdown m Stimulate __ Plugging __ Perforate ~X Pull tubing ~ Alter casing __ Repair well w Pull tubing __ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510 4. Location of well at surface 961' FNL, 1386' FEL, At top of productive interval Straight Hole At effective depth 5. Type of Well: Development Exploratory Stratigraphic Service At total depth Sec. 33, T8N, R9W, SB&M 6. Datum elevation(DForKB) 165' GL feet 7. Unit or Property name Swanson River Unit 8. Well number SRU 31-33WD 9, Permit number/approval number 10. APl numl~er 50-- 133-20336-00 11. Field/Pool Swanson River/Sterling 12. Present well condition summary. Total depth: measured true vertical Effective depth: measured true vertical '2461 feet Plugs (measured) 2461 feet 2413 feet Junk (measured) 2413 feet Casing Conductor Production Liner Perforation depth: Length Size Cemented 80' 10-3/4" Driven 2461' 7" 800 sx 2015' 5-1/2" 100 sx measured /True Vertical 2100-2140' MD; 2162-2242' MD; 2256-2284' ~~i~l Re-perforated Interval 2100-2140' MD; 2162-2242' MD; 2256-2284' ~bing(size, grade, and measureddepth) 2-7/8" EUE 8RD @ 1917' MD PackersandSSSV(typeand measureddepth) Model F-1 packer e 1917' MD Measured depth True vertical depth 0-80' 0-80' 0-2461' 0-2015' MD; 2313-2383' MD MD; 2513-2383' MD 0-2461' 0-2015' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5500 0 800 Subsequent to operation 715 0 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run N_LA I Daily Report of Well Operations ..~ Oil m Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. .Signed ,¢~.,,,~.,~~ TitleCook Inlet Form 10-404 Rev 06/15/88 860 Service Water D i sposa I Engineering Manager Date d'u ,c^T ................ AUG-22-' 89 06:53 ( ARCO Alaska, Inc. 6ubel~lao' of Atlenttc Richfield Comp4ny WELL OONTRACTOR REMARK8 ID:?'ANSON RIUER TEL N0:265~TM ~504 POi WELL SERVICE REPORT IOPERATION AT REPORT TIME r (_.,.,,,.,C /,. ~ ._ 1~7oo .. 0~3o ¢ U 0 ~30- 0 qo ) 3 $2.-- )q.es IF3 s- 17/3- CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Temp. IChill Faotor I Vlelblllty J WInd Vel. 181gned .............. - AUG-22-'89 06:51 ID:~IANSON RIUER TEL NO: ~657 ~ ~503 P06 REMARKS CONTINUED: I q/E- 2. 0 Go DESCRIPTION' DALLY ACCU~. TOTAL CAMCO OTIS ;SCHLUMBERGER · . DRESSER.ATLAS ,. DOWELL .... __..__ _... _ , HALLIBURTON __ - ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Methanol ..... Supervision ,..~ ,-. F ~ _~' .[~,~Y -'-' ....... ,. ,._. I~e-Job Safety Meeting i..~'k*.,.:.','~ .,,.:,~:, :.::;t ~,,.,-',,.;'. ....... AFE ., ...~-__. . . _._-_ -._-.-~. _ .... .=.- ...... M. , ......... ,, ~ , .................. , ,,,,, TOTAL FIELD ESTIMATE ..................................... _ ...... _.__I' s'~ned~.,~, ...... ~_¢p/x,/ .... ...... (~..~ . ARCO AI.~SKA INC. Cook Inlet/New Ventures Engineering TRANSMITTAL #349 TO: John Boyle FROM: Tom Wellman COMPANY: AOGCC DATE: Sept. 6, 1989 COMPANY: ARCO Alaska, Inc WELL NAME: SRU 242-16 Transmitted herewith are the following 'Blue Sepia Sepia . .Line Folded Rolled Mylar Tape DIFL 2" &5" . . 1 1 .BHC 2" & 5" 1 1 i CZD/CN 2" & 5" 1' 1 , ACBL/V/S 1 1 EPILOG'GAS ID ' 1 1 EPILOG-INTERPR. RESULTS " ' 1 1 -, PDK-100 1 1 , (~AMMA RAY SRI,) 31-33WD 1 ..... 1 ..... , ,, .......... P-..-r-~, ~ ~ x .... ~ .... ,, , Receipt AcknoWledgement: Date: ATrN: Judy ATO ' - Post Office Box 100360 ' 99510-0360L,-/ ~ Anchorage, AK ^lask,~ ..~1 & :~,. ARCO Alaska, Inc{ Post Office~,.._~ ,o0360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures August 9, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Results of Pump-In Temperature Survey of SRU 31-33WD Swanson River Field Dear Mr. Chatterton: This is to submit the results of the pump-in temperature survey (PITS) that was performed on SRU 31-33WD on May 14, 1989. The test was done to prove that current injection practices (over parting pressure) are not resulting in fractures that extend through confining zones enabling disposal water injectant to enter any fresh water strata. The pump-in temperature survey was obtained in accordance with the submitted sundry, as previously approved by your office. The results prove that this well is injecting up to -1970' MD, which is 270' below the legal injection cut-off depth of 1700' (see attached survey). If you have any questions concerning this matter, please contact Stacy Strickland at 263-4914. Sincerely, T. S. McCorkle TSM:SLS:ch:0004 Attachment cc: S.W. Ohnimus A. R. Kukla UNOCAL Corporation Marathon Oil Company ARCO Alaska, Inc. is a Subsidiary of AflanticRichfieldCompany AR3B--6279 STATE OF ALASKA Al( .)IL AND GAS CONSERVATION COM~. REPOFI'I OF SUNDRY WELL OPEFIATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate __ Pump- I n Pulltubing__ Alter casing ~ Repair well ~ Pulltubing~ Other...~.X Temp,;' Survey 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510 4. Location of well at surface 961' FNL, 1386' FEL, Sec. 33, T8N, Rgw 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 165' GL 7. Unit or Property name Swanson River Unit 8. Well number SRU 31-33WD At top of productive interval Straight Hole At effective depth At total depth 9. Permit number/approval number 10. APl number 50-- 133-20336-0 11. Field/Pool Swanson River/Sterling feet 12. Present well condition summary Total depth: measured true vertical 2461 ' feet Plugs (measured) 2461 ' feet Effective depth: measured true vertical 2413 ' feet Junk (measured) 2413 ' feet Casing Conductor Production Liner Perforation depth: Length Size Cemented Measured depth 80' 10-3/4,, Driven 0-80' 2461' 7" 800 sx 0-2461' 2015' 5-1/2" 100 sx 0-2015' measured 2100-2140' MD; 2162-2242' MD; 2256-2284' MD; 2313-2383' MD truevertical 2100-2140' MD: 2162-2242' MD~ 2256-2284' MD; 2313-2383' MD ~bing(size, grade, and measureddepth) 2-7/8" EUE @ 1917' MD Packers and SSSV ltype a~d ~ela~tcre~l¢) epth) Model F-1 packer 13. Stimulation or cement squeeze sUmmarY True vertical depth 0-80' 0-2461' 0-2015' 14. Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3705 BPD 0 820 Subsequent to operation 3857 BPD 15. Attachments · 16. Status of well clasSification as: ! Copies of Logs and Surveys run X Daily Report of Well Operations _% Oil __ Gas ~ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 8OO Service Water Disposal .Signed ¢f~'~, ~,¢¢/,/,~ ~ Form 10-404 Rev 06/15/88 TitleOgok Inlet Enqineerinq Manaqer Date ¢/'~/~ SUBMIT IN DUPLICATE _. ...... r,l~".,"'-].a-':3'9 22:4:3 [!"- 'SI-~t.I PI'..',EP TEL t..1,3:265i,' - :3!0 FOZ ska, Inc. ~ WELL SERVICE REPORT' SubIIdilry of Atlantic Richfield Company .... 'L IPBOT [~-~LO. DISTRICT. STATE ,,~ ~'--]DAY$ ~OATE / j . ~/~ - ~,'/~ ~1~ _ I .................. : ..................................... 11:15' i t,, lt /- : .~ ~,, ~. %,, /,~ J;~ CHEqK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I 1Tamp, I Chill Factor I Visibility [Wind Vel. TEL HO: 265].~7°7 REMARKS CONTINUED: . ,. DESCRIPTION DAILY AccuM. TOTAL CAMCO '6i'i~ .... SCHLUMBERGER ORESSER.ATLA$ .... . ...... ~ ~'2~ =~''' L._~.7 2- -- DOWELL H~UBU~tO. ...... -~/_~,~' -- ~/'o.5' - AnCT~C CO~L TUn~.G B. J. HUGHES Diesel ..... _. , -~lethanol Supervision ..... Pre.Job Safety Meeling ..... AFE _ ........... 1,1 11 , -- TOTAL FIELD ESTIMATE ........... ~ ? ARCO Alaska, Inc;1 Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures August 9, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached is an Application for Sundry Approval to Re- perforate the existing intervals in SRU 31-33WD. The proposed intervals (2100-2140' MD; 2162-2242' MD; 2256- 2284' MD; 2313-2383' MD) will be shot using a 2-1/8" strip perforating gun at 4 SPF. With your approval, we would like to begin this work as soon as possible. If you have any questions, please contact Stacy Strickland at 263-4914. Sincerely, T. S. McCorkle TSM:SLS'ch:0002 Attachment cc' S.W. Ohnimus A. R. Kukla UNOCAL Corporation Marathon Oil Company ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 STATE OF ALASKA ,KA OIL AND GAS CONSERVATION COM~ .ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair welt Change approved program __ Operation shutdown __ Re-enter suspended well ~ Plugging __ Time extension __ Stimulate ~ Pulltubing ~ Variance__ Pedorate X Other 2. Name of Operator ARCO Alaska, INc. 3. Address P. 0. Box 100560 Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 961' FNL, 1586' FEL, Sec. 55, At top of productive interval Straight Hole At effective depth T8N, R9W At total depth 6. Datum elevation (DF or KB) 165' GL feet 7. Unitor Property name Swanson River Unit 8. Well number SRU 31-33WD 9. Permit number 10. APl number 50--155-20556-00 11. Field/Pool Swanson River/Sterling 12. Present well condition summary Total depth: measured true vertical 2461 ' feet Plugs (measured) 2461 ' feet Effective depth: measured true vertical 2413 ' feet Junk (measured) 2413 ' feet Casing Conductor Production Liner Perforation depth: Length Size Cemented 80' 10-3/4" Driven 2461' 7" 800 sx 2015' 5-1/2" 100 sx measured/True VertiCal 2100-2140' MD; 2162-2242' MD; 2256-2284' P~~,U:Re-Perfs 2100-2140' MD; 2162-2242' MD; 2256-2284' Tubing (size, grade, and measured depth) 2-7/8" EUE 8RD @ 1917' MD Packers and SSSV (type and measured depth) Model F-1 packer @ 1917' ND RECEIVED ..Alaska 0[1 .& Gas' ' ~ (,0,~,:,. Commission Measured'de'pt~~ch0raC8'' True ve~ical depth 0-80~ 0-80~ 0-2461' 0-2461' 0-2015' 0-2015' MD; 2313-2383' MD MD; 2313-2383' MD 13. Attachments Description summary of proposal Detailed operations program BOP sketch 14. Estimated date for commencing operation August, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service Water Disposa I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~. ~'~.~ Title Cook Inlet Engineering Manager Date Signed FOR COMMISSION USE ONLY Conditions of approval'Notify Commission so representative may witness '~. i Approval No. Plug integrity ~ BQ,P Test __ Location clearance __ Mechanical IntegrityTest2L Subsequent form required 10- J¢ ~ Approved Copy ' Returned -. Original Signed By Approved by order of the Commissioner David W. Johnston Commissioner Date FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SRU 31-33WD Reperforation Procedure SR 67 Objective: To reperforate 218' of open interval to increase water injectivity. Well Data: Completion: Last PBTD Tag: Pressure Data: Tie-in Log: 2-7/8" EUE 8RD Tbg. to 1917' MD 2410' WLM (8/1/89) Tbg=900psi; PC=0psi; SC =0psi CBL of 7/10/81 (main pass) Procedure: Note: Verify that Sundry approval has been obtained prior to performing this work. 1. RU slickline. Pressure test lubricator to 4000 psi. 2. RIH with 2-3/8" gauge ring and tag bottom. 3. RDMO slickline unit. 4. MIRU conductor line unit. Pressure test lubricator to 4000 psi. 5. Shut-in well. RIH with perf gun/CCL. Tie-into perf interval: DIL Depth [5/22/81) (CBL is 12' off-depth with DIL) Footage SPF 2100-2140' 40'MD 4 2162-2242' 80'MD 4 2256-2284' 28'MD 4 2313-2383' 70'MD 4 TOTAL 218' MD Recommended Guns ?ilaska O~l a Gas Cons. Commission ,anchorage Gun Hole Hole Company Type Size Phasing Depth Diameter Schlumberger Enerjet Strip 2-1/8" 0° 10.25" 0.36" Atlas Silver Jet 2-1/8" 0° 10.55" 0.39" NOTE: Gun orientation should be down (at hole bottom) and strip rollover protection should be used. SRU 31-33WD Re-perforation Procedure SR 67 - Page Two 6, 7, . 9, Perforate intervals. POOH. Check gun to confirm that all shots have fired. Repeat Steps 5-7 as needed to perf all intervals. RDMO. Place well on injection. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6OO1-A E-Line BOPE's ~ Grease Head/ Hydraulic Packoff · ,-..- Lubricator Extension Manual Rams Swab Valve Double Maste~ Valves II Wellhead ARCO Alaska, Inc.{' Post Office Bo,( !00350 Anchorage .z~la~k.a !)95'., 3..G360 Telephone 907 ~-, _gtsv,'art McC.'.;~ . May 9, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Sundry Approval:-~rature Surveys SRU 21-33WD & (~U 31-33~_,~3 Swanson River Field- ' Dear Mr. Chatterton: ARCO Alaska, Inc. requests approval to perform the attached pump-in-temperature surveys on SRU 21-33WD and on SRU 31-33WD to prove that current injection practices are not resulting in fractures that extend through confining zones enabling disposal water injectant to enter any fresh water strata. Such testing is warranted as recent data shows these wells to be injecting over parting pressure. The recommended surveys will make multiple temperature passes from 1200' to PBTD after injecting hot lease water into each well. The resulting data will define where the hot fluid travels when injection is over parting pressure. ,, If there are any questions pertaining to this matter, please contact Carol Baker at 263-4643. Sincerely, T. S. McCorkle TSM:CMB:ch:0015 Attachment CC: G. A. Graham A. R. Kukla UNOCAL Corporation ~;'~ Marathon Oil Company ARCO Alaska, Inc, is a Subsidiary of AtianticRichfieldCompany AR3F~ ~)'::i STATE OF ALASKA't'~''' ,_, ,SKA el L AND GAS CONSERVATION COM M'I~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter cas;rig __ Repair we!l __ Change approved 0rogram __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stim ulate __ Pull tubing __ Variance __ Perforate __ Other X Pump-in Temp. survey 2. Name of Operator ARCO Alaska, Inc. 3. Ac]cress P. 0. Box 100360 Anchorage, AK 99510 4. Location of well at surface 961I FNL, 1386' FEL, Sec. 33, T8N, R9W 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service __~ 6. Datum elevation (DF cr KB) 165' GL feet 7. Unit or Property name Swanson River Unit- 8. Well number SRU 31-33WD At top of productive interval Straight Hole At effective depth At total depth 9. Permit number 10. APl number 50-- 133-20336-00 11. Field/Pool Swanson River/Sterling 12. Present welt condition summary Total depth: measured true vertical 2461 ' 2461' feet feet Plugs (measured) Effective depth: measured true vertical Casing Conductor ;~XX Production Liner Perforation depth: 2413' 2413' Length Size feet feet 80' 10-3/4" 2461' 2015' measured 2100-2120'; truevertical 2100-2120'; 711 5-1/2" 2140-2162'; 2140-2162'; Tubing (size, grade, and measured depth) 2-7/8" EICE ~IRD @ 1917' MD Packers and SSSV (type and measured depth) Model F-1 packer @ 1917' MD Junk (measured) Cemented Measured depth driven in 0-80' 800 sx 101:) sx 2182-2256'; 2182-2256 '; 0-2461' 0-2015' 2264-2284'; 231~-2383' 2264-2284'; 231~-2353' True vertical depth 0-80' 0-2461' 0-2015' RECEIVED BOP sketch X .... " 13. Attachments Description summary of proposal __ Detailed operations program __X 14. Estimated date for commencing operation May, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Service Gas __ Water Suspended __ Disposal 17. I hereby certify th at the foregoing is true and correct to the best of my knowledge. ,/ Signed ,¢~,/~. ~~ Title Cook Inlet Engineering FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Manager Date .,¢'"~/¢~' IApproval No. /~;I.. ~,~ .~ / Plug integrity __ BOP Test __ Location clearance __ 4 c~Z~. Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commissioner OR!GI.~:;,~! qt"',~"~D BY I_ONNIi! ¢,,, ?,MITN .~.0 .r,...,.,,md CoPY Retu. rned Commissioner Date ,,~-"-/~..~ ~L~ ~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Pump-In-Temperature-Survey SRU 31-33WD SR 40 Objective.: To determine the interval(s) receiving disposal water in this well while injection is maintained over parting pressure. Well Data: Completion Perforations: Last PBTD tag: Current Pressures: Est. Parting Pres.: 2 7/8" EUE 8RD tbg Set @ 1917'MD 206' Total; Top Most @ 2100' MD, bottom @ 2383' MD 2180' WLM on 4/7/89 (2.2" gauge ring) =730 psi tbg. inj. pres.; PC = 0 psi 590 psi surface injection pressure Procedure: 1. SI well for at least 24 hours. . Hold safety meeting. Assure that at least 300 Bbls of heated (150°F+) lease water is on location. (A steamer can be used to heat the fluid). 3. RU E-line. Pressure test lubricator to 1000 psi. . RIH with CCL/temp tools (CCL on top). Record temperatures from 1200' MD to PBTD. Do not exceed a 30 fpm line speed below 1200' MD. 5. Tie-in with tbg tall. 1 Re-log bottom 200' at 30 fpm to verify temp tool repeatability (down mn). Leave tool on bottom. . RU pump truck and tie into tbg. Pressure test lines to 1000 psi. Pump at least 300 Bbls of heated lease water (150°F+) at over 700 psi surface injection pres. SI well. 8. POOH to 1200' MD at 30 fpm. 9. Log down to PBTD at 30 fpm recording temperature data. 10. Repeat steps 8 and 9, as needed, to determine the intervals which receive water injection (these areas will be warmer than surrounding intervals). A minimum of 3 hourly passes will be required. 11. POOH. RDMO. 12. Return well to injection. ARCO Alaska Inc. Is a subsldlmy of Atlantic Richfield Company AR3B-6OO1-A 4t9' 4~0' 4- ~" H~ I SQO! IdOOtL Jr.I BAKER SRU 31 - 33 W.-D. CASING & TUBING DETAIl. SECTION 33 T. 8#q R. gw. SM E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension L Manual Rams Swab Valve Double Maste~ Valves Wellhead t' TABLE Wells under Evaluation for Rate Potential 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34 -4 Wells being Evaluated for P&A/Future Util itx 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Production 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 ~343-33 ATTACHMENT E- 1 Injection Well Data Water Disposal. Wells SRU 31-33W SRU 32-33W SRU 41=33W SRU 21=33W scu 43-4w. c Avg. Rate(BPD) 3274 125 2805 Max. Rate(BPD) 4500 4500 4500 4500 4500 Avg. Press(psi) 769 778 913 735 Shut In Max. Press(psi) 1000 I000 1000 1000 1000 Depth of Inj.(ft.) 2100 2100 3100 Depth of Well(ft.) 2461 2520 3000 3__84 6660 Gas Injection Wells SCU SCU SCU :U :U SCU scU SCU SRU SRU SRU Ave. Rate(MCFD) SRU 331-2J I~ Max. Rate(MCFD) 31-4-2 39,950 45000 323-4 35,680 45000 332-4 27,640 45000 3¢1-4 37,640 45000 341-8 30,300 45000 3i2-9 44,000 45000 321-9 29,940 45000 323-9~ 35'920 45000 343-33 0 45000 332-15 0 45000 312-22 0 45000 314'27 0 45000 0 45000 5075 5370 5095 5355 5160 5270 5155 5105 Shut In Shut In Shut In Shut In Shut In 6 7 -?9 5800 '5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 10291 10394 10470 10226 10256 10183 10294 10280 10695 11388 '10754 11146 10804 11520 107.75 11119 10850 10814 10'785 10745 10750 10995' 11982 11000 11434 11620 -8- ARCO Alaska, Inc. 110500 ALASKA OIL AND OAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.232 SWANSON RIVER FIELD - UNIT 05i~50 09-Sep-87 August 1~87 : I I Name o{ Operator Field and Pool Month and Year o{ Injection :1. WELL:2. API NUMBERI3. C:4. FIELD|5. DAYS: TUBING PRESSURE : CASING PRESSURE :DAILY AVERAGE INJECTION:TOTAL MONTHLY INJECTION I NO. I 50- I LI & POOL I IN I I I I I I ' I Al CODE I OPER I&. MAXI7. AVERAGE|8. MAXI~. AVERAGE|10. LIQUID Iii. GAS I 13. LIQUID I 14. GAS 314-4 1133-10104-00 323-4 1133-10106-00 552-4 I133-10107-00 · 541-4 1133-10109-00 341-8 1133-10120-00 ._.712-9 1133-10123-00 323-~ I 1.33-1012&-00 1345-33 I 1.53-101&8-00 12-10 1133-2020&-00 321-9 1133-10125-00 43-4WD 1153-10111-00 I I I I I I I I I 1 I I I I I I I I I I I I SI I I |___SI I I 772100 I I 772100 I I 772100 1 I 772100 I I 772100 1 I 772100 I I 772100 I I 772100 I I 772100 I I 772100 I I PSIG I PSIG I (BBL) I (MCF) I (BBL) I (MCF) I I I I : I I 30 15,450 I 0 I 0 1 30 15~500 I 50 15,550 I 0 I 0 1 30 15 ~ 350 30 15,300 I 0 I - 0 I. 0 I 0 1 30 15~4~0 I 0 'I I I I I- I '0 1 I I I I I I I I I I I I I I I I I I I I PSIG I PSIG I I I 4,958 15,300 I 0 I 0 I 5,005 11,040 I 5,141 12~860 I 0 I 0 I 4~45 11,240 I 4,~28 12~&O0 I 0 I 0 I Ol OI 4,9~1 I1~960 I 0 I 0 I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ....... I 2,359 0 1 &5& I 2,37& I 0 1 1~109 I 2,368 I 0 1 0 1 1~815 I 0 1 I I I I I .I I I I I 1 I I I I I I I I 0 1 I I I I I I I I I I I I I I I I I I I I II hereby certify tha~ the ~oregoing is true and correct ~o the best o~ my knowledge I I I Si gned I I 1 ITitle I INSTRUUTIONS DN REVERSE SIDE 39,25~ I I 1~177,1&5 0 I I 0 31,632 I I ~48,955 37,120 I I. 1,113,&09 0 I I 0 40,483 I I 1,214,475 35,148 I I 1,054,428 0 I I 01 0 I I 0 25~70& I I 771~1B2 I 0 I I I I l I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I15. I I I I I I I I I I I I I I I I ITOTAL I I I 0 I 6,279,814 I i Submit in Duplicate Form 10-405 Rev. 12-1-85 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC--~5.2.52 ARCO Alaska, Inc. 116)500 Name of Operator SWANSON RIVER FIELD - UNIT 051994 Fi eld and Pool August 1987 Month and Year of Injection :1. WELL:~.i API NUMBER:.5. C : NO. : 56)- | L ~ : : A ; ; : S I I I S 1512-22 1135-10147-00 IG :514-27 ~133-10154~A0 :G ~551-27 ;155-10156-00 :G ;452-15 :1.55-10141-00 ;G -,1-55WD: 15.5-10162-00 :D ~ .51-55WD | 1.5.5-20556-6)0 ; D ~52-.55WD~ 1.5.5-10164-00 ~D :41-55WD:1.5~-1A167-00 :D : : I I I · I I - I I I I 1 I I I I I I I I I I I : I I I I I I I I I I I I I I I I I I I I I I I I I I I 4. FIELD~5. DAYSI TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION & POOL CODE I OPER |6. MAX|7. AVERAGE~8. MAXIg. AVERAGE~IO. LIQUID 111. GAS I I 1.5. LIQUID I 14. GAS I I I PSIG I F'SIG (BBL) I (MCFI I (BBL) I (MCF) I I I I I I I I PSIG I PSIG I I I I I I I I I I · I I 0 I 0 Ol Ol I I I I I I I I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I 2,675 I I 77,581 2,770 I I 80,518 2,071 I I 62,119 145 I I 4,.552 I I I I I I I I l I I I I I I I I I I I I I I l : I 772100 772100 772100 772100 7720.56 7720.56 77205& 7720.5b 734 746 759 7.51 I I I I I I I I I I I I I I l I I I I l I l I I I I I I I I I I i I I i I I I II hereby certify that the foregoing is true and correct to the best of mY ~nowledge I I :Signed I I. ITitle I Form 10-405 Rev. 12-1-85 Date INSTRUCTIONS ON REVERSE SIDE I I' I 'I 15. I I I I I I' I I I I I I I I I I I I I I I I I I I I I I TOTAL I 224,.570 I 0 I I I I I Submit in Duplicate V~UUHU~, PRUDHO£ PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY UNII 6-11 UNIT S-14 UNIT T-1 UNIT T-7 UNIT U-3 UNIT U-4 UNIT U-5 UNIT U-9 UNIT U-lO UNIT X-6 UNIT X-11 UNIT X-23 UNIT X-24 bNIT X-26 UNIT Y-3 UNIT UNIT UNIT Y-7 UNIT Y-11RD BAY UNIT Y-18 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL SWANSON RIVER, HEHLOCK 0 ARCO ALASKA INC SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT ...... SOLDOTNA CK UNIT SOLDOTNA CK UNIT IL POOL 314-4 323-4 332-4 341-4 341-8 312-9 321-9 323 -9 412-10 343-33 UNIT OR LEASE TOTAL 309,534 264,425 174,467 380,162 602,357 515,072 264,751 183,322 244,173 294,661 149,980 173,544 262,057 '282,344 76,492 49,131 84,323 22,223 43,679 306,429 14,519,526. 39,536,156 84,445,002 39,536,156 88,810,140 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 SOLDOTNA CREEK UNIT SHUT-IN SHUT-IN 1,148,650 31 1,080,598 31 871,402 31 1,090,670 31 153,799 6 1,246,967 30 749,378 31 1,089,518 31 7,430,982 6,975,040 7,115,160 1,241,472 2,275,741 2,727,957 2,791,476 2,551,632 1,790,980 1,767,557 6,174,166 5,618,096 3,530,342 5,273,083 3,169,181 3,942,403 1,968,753 2,653,403 102,640 597,32,1 6,409,296 1,388,876 294,742,915 233,327,280 207,759,340 231,764,932 218,694,647 304,044,302 33,033,842 170,911,513 111,413,676 - - ENHANCED RECOVERY - - WELL NAME AND NUMBER ARCO ALASKA INC SWANSON RIV UNIT 331-27 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL TRADING BAY, MICDLE KENAI C OIL POOL UNION 0IL CO CF CALIFORNIA ADL-18731 TRADING BAY ST. A-SRD-2 TRADING BAY ST A-12RD TRADING BAY ST A-26 TRADING BAY ST A-29 UNIT OR LEASE TOTAL POOL TOTAL TRADING BAY, MIEDLE KENAI D OIL POOL . UNt0N 0IL CO OF CALIFORNIA ADL-18731 TRADING BAY ST A-SRD-2 TRADING BAY ST A-19 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL ALASKA INDIVIDUAL HELL PRODUCTION FOR HARCH, 1987 OIL(BBL) ~I'R(BBL) GAS(MCF) DAYS S't4ANSON RIVER UNIT SHUT-IN SHUT_iN.'""'%~ SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN 7,430,982 7,430,982 CUM. OIL CUM. WATER 413,934 15,582,616 4,498,822 6,267,061 7,3U8,684 21,618,136 CUM. GAS 28,263,659 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 2O AAC 25.252 ARCO Alaska, Inc. 110500 SWANSON RIVER FIELD - UNIT 051994 December 1986 Name of Operator Field and Pool Month and Year of Injection ;1. WELL:2. API NUMBER~5. C;4. FIELD;5. DAYS: TUBING PRESSURE ~ NO. ~ 50- ~ L~ & POOL ~ ~ I A~ CODE I I I SI I I l___SI 1512-22 1155-10147-00 I G I 772100 -~514-27 I155-10154-00 I G I 772100 ~ii~:~51-27 I155-1015&-00 I G I 772100 ~:=1452-15 1155-10141-00 I G I 772100 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I- I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I' I I I I I I I I I I I I I I I I I I I I . . --. .... I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I (MCF) I (BBL) I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I t I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I - I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I I I ,m -- ~''.I~ I.- : : : : : : t:{ iZ I I I I I I I I I I I I I I I I ...... I I I I ~ ~'l I15. I I : Alaska Oil & Gas I PSIG I PSIG I PSIG I PSIG I ii hereby certif~ that the ~orego~:ng is true and correct to the best o{ my knowledge ISigned _ I I I Supervise, New Ventures Compliance and Revenue ITitle I Form 10-405 Rev. 12-1-85 (BBL) (MCF) INSTRUCTIONS ON REVERSE SIDE : : - An:ho~?-: I I I I I' I ITOTAL I 0 I 0 I I I Submit in Duplicate i I I I I I I I I I I I I I I I I I I I ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051950 Fi eld and Pool December 1986 Month and Year of Injection :1. WELL I. NO. : ~14-4 I 525-4 -! 552-4 :~'~ 541-8 ~ 512-9 I 525-9 1545-55 1412-10 ~ 521-9 I I I I I I. I I 1 I 1 2. API NUMBERI5. CI4. FIELDIS. DAYSI TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION 50- I LI & POOL I IN I I I I I Al CODE I S'I I I___SI I I 155-10104-00 IG I 772100 I 50 15,500 I 5,013 12,500 I 1,560 I I ~2,501 I I ~75,018 155-10106-00 IG I 772100 I 50 15,650 I 5,278 15,250 I 1,976 I I 29,526 I I 885,785 155-10107-00 IG I 772100 I 50 15,500 1~5-10109-00 IG | 772100 I 50 15,550 I 5,157 11,200 155-10120-00 IG I 772100 I 50 15,500 I 4,882 11,400 I 1,548 I I 25,121 I I 695,626 153-10125-00 IG .I 772100 155-10126-00 IG 772100 I 17 15,200 ~ 5,140 11,600 ~ 1,588 I ~ 25,550 I I 450,602 155-10168-00 IG 772100 I 0 I 0 I 0 155-20206-00 IG 772100 I ¢) I 0 I 0 155-10125-00 IG 772100 I 50 15,540 I 5,150 11,600 I I I I I I I I I I I I I I | I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I -, I I I I I I I I I I I I I I I I I I I I I , I I I I I I I I I I I! hereby ~erti{~ that thee , -~golng is true and correct to the best o~ m~ knowledge 'l I Super Ne~ Ventures Compliance and Revenue De ITi~le I FOrm 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE I15. I I I I I ITOTAL I ! I ~ ........~'~.' ~'I I I I I I I I I I 0 I 6~288,655 ~ I Submi~ in Duplicate LEASE NO. ]ENHANCED RECOVERY] COMP.DATE . + ~ STATUS PRODUCT JAN FEB NAR ALASKA INDIVZDUAL'HELL%DDUCTION FOR 1986 YEAR · APR MAY JUN JUl AUG SEP OCT NOV DFC TOTAL CUM _ ~~ SHANSON RIVER, HEMLOCK ARCO ALASKA SOLDOTNA CK UNTT 316-~ APT 155-10106-00 UNIT05[950 · 08/15/60 HTR I$INJ GAS 1055857 1026590 1189909 1165806 1228646 1211657 1257286 1288552 1505704 1125075 1022955 975018 15808655 291785545 SDLDOTNA CK UNIT ~25-4 APT UN/T051950 06/01/61 HTR GINJ GAS 9'26806 895795 1014489 1021515 1095847 1095954 1110742 1160265 1165222 986857 950909 885785 12505942 250168775 SOIDDTNA CE UNIT ~2-4 APT ]~5-]0]D7-fl~ UNIT051950 OIL 06/05/60. HTR 1G[NJ GAS 729520 694699 694'207 768554 848986 808659 855755 906429 908925 775879 755048 721155 9465572 Z0555481~ SOL~OTNA £K HNTT ~4]-4 APT UN/T051950 05/21/60 HTR 1GINJ GAS 964182 959897 1105510 1004702 1191650 1125455 1151894 1167267 1142665 989567 1047597 898524 12728466 Z28845715 SGIDOTNA CK UNIT 54]-8 APT UNIT051950 07/14/61 HTR 1GINJ GAS 772050 .721011 855765 795562 858795 851801 877466 885419 861454 802085 790782 695626 9761772 217114264 SDLDOTNA CE UNIT 51~-q ' APT UN[T051950 10/09/60 HTR 1G/NJ GAS 1150860 1105246 1275468 1219454 1266462 1242821 1268188 1518592 1512222 1120415 1159677 1054878 14454281 50078~545 SOLDOTNA CE UNIT 52]-9 APT UNIT051950 07/19/61 HTR 1G/NJ GAS 787999 770786 941516 857121 859651 824009 859794 852454 865441 701058 657884 629091 9546564 51111755 SOLDOTNA CE UNTT ~25-9 APT UNIT051950 07/17/61 HTR 1G/NJ GAS 868162 887705 1057404 1002092 1041454 1027008 1054526 1105448 1110180 1002927 967125 450602 11552455 168145955 50LDOTNA CK UNIT UNIT051950 Oil 06/11/72 HTR 1HINJ GAS SOLDOTNA CK UNIT UNIT051950 OIL 05/08/61 HTR iGINJ GAS SNANSON RIV UNIT UNIT051994 OIL 10/24/59 HTR 1GINJ GAS SNANSON RIV UNIT UNITOSI994 OIL 08/04/61 HTR 1GINJ GAS 452-15 APT 155'10168-00 AP1 153-10141-00 15888. 111~15676 ' 6018206 9029559 54-15 APl 133-10142-00 2056925 4645550 ' I!! ~ LEASE NO.. I ENHANCE9 RECOVERYI COMP.DATE 4 .-+ STATUS PRODUCT JAN FER NAR · ~~ SHANSON RIVER, HEMLOCK SHANSON RIV UNIT 51Z-ZZ API UN~T~51994 OTL YEAR APR NAY JUN JUL AU~ SEP OCT NOV DEC TOTAL 155-10147-00 CHH _ 08/11/62 HTR 1GINJ GAS SHANSON RIV UNIT UNIT051994 OIL 514-27 API 135-1015fi-00 875988 2q017269 06/14/60 HTR 1GINJ GAS SHANSON RIV UNIT UNITOS]g94 OIL 551-27 API 135-10156-00 78352178 02/17/58 HTR 1GINJ GAS - ARCO ALASKA INC 282656 OPERATOR TOTALS OIL HATER 8,557,995 POOL TOTALS GAS 7,0ql,527 7,852,406 8,187,502 8,680,226 7,q99,819 6,288,655 1,929,187,012 7,215,596 8,115,868: 8,569,449 8,595,451 8,667,789 7,311,775 95,601,665 SHANSON RIVER, HEMLOCK OIL HATER 8,357,995 FI'ELD GAS 7,041,527 7,852,406 8,187,302 8,680,226 7,499,819 6,288,655 1,929,187,012 7,215,396 8,115,868 8,569,449 8,395,451 8,667,789 7,511,775 95,601,665 SHANSDN RIVER TOTALS OIL HATER 8,337,995 GAS: 7,041,527 7,832,40~ 8,187,502 8,680,Z26 7,499,819 6,288,655 1,929,187,01.~ 7,215,596 8,113,868 8,569,449 8,595,451 8,667,789 7,511,775 93,601,665 SWANSON RIVER WELL SRU 312-22 SRU 314-2-7 SRU 331-27 S~CU 323-4 SCU 332-4 SCU 341-4 SCU 341-8 SCU 312-9 SCU 321-9 SCU 323-9 SRU 432-15 TYPE Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Water Injector STATUS AS OF 1/1/88 Shut-in Shut-in Shut-in Injecting Injecting Injecting Shut-in Injecting Injecting Injecting Shut-in GRU13/2c RECE Alaska 0i1 & Gas Cons. Commission Anchorage t STATE OF ALASKA ; ASKA OIL AND GAS CONSERVATION i MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~_ Plugging '- Perforate ~ Pull tubing Alter Casing r-- Other Z~ 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360 Anchorage, AK 99510 4. Location of wellatsurface Sec. 33, TSN, R9W, and Sec. 4, TTN, R9W 5. Datum elevation (DF or KB) 6. Unit or Property name Swanson River Field 7. Well number SRU 32-33WD SRU 31-33WD, SCU 43-4WD At top of productive interval At effective depth At total depth 8. Approval number 7-795 9. API number 133-10164-00 Feet 50--13;~-20;~36-00, 10. Pool Stet I i ng 133-10111 11. Present well condition summary See attached schematic Total depth: measured feet true vertical feet Effective depth: measured feet true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Plugs (measured) Junk (measured) Cemented Measured depth True Vertical depth true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure R CEIYED NOV 13, Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10.404 Rev. 12-1-85 / / Manager, Cook In let Engineering Date////,/Z-'~,~ ~ Submit i~'"bUl~licate SUBSEQUENT REPORT PRESSURE TESTS SRU 31-33WD, SRU 32-33WD, AND SCU 43-4WD Attached are three (3) Well Service Reports which document the production casing pressure tests on water disposal wells SRU 31-33WD, SRU 32-33WD, and SCU 43-4WD. The wells were tested in accordance with Rule 6 of the AOGCC Area Injection Order to a test pressure of 1500 psi. The SRU 32-33WD did not meet the criteria of Rule 6 which states that there cannot be more than a 10% decline in the test pressure over a 30 minute pedod. This well is currently shut-in pending work on the tubing hanger which is the source of the leak. Repairs should be completed by the end of December at which time you will be notified of the production casing retest. The SRU 31-33WD and SCU 43-4WD held 1500 psi (within 10%) for 30 minutes. NOV t ~ '!~i~'~ OCT-~?-' 8? ~3:19 !D: NSON ~u~4¢llry Of At~anfic IIItcl~flelcl Comp,l~ly TEL CONTRACTOR REMARKS WELL SERVICE REPOI IOPERA~'ION AT'-REPORT /~ .. z. ~,..c; AI-~ska Oil & Gas Cons. Commi'ssio;~ Anchorage CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W.,th, 1 T. mp. I Chill Fa~tm I Vl,lblllly i Wind V.i' I$1gnld ~ CT;, RIDOrt . . ~r .= __.=. ~.__. ...... ,/',., OCT-2?-' 8? 23:2I i · · ~9~5 P02 Form 3160--5 (November 1983) (Formerly 9--331) i' UNITED STATES (Other tnaUmeUona on D~ARTMENT OF THE INTERIOR ,,~) BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not ~me thl~ form for proposals to drill or to deepen or pluf back to a ~tferont reservoir. Use "APPLICATION FOR PERMIT--" for such p~) O~L [~] Gw~OLL ~] O'rnSS WELL 2. NAME OJ' OPEmATOR ARCO Alaska~ Inc. Post Office Box 100360 Water Disposal Wells Anchorage, Alaska 99510 LOCATION Or WELL (Report location.clearly and in aecordanc~ with any State requirements.· See also space 17 below.) At surYae~ Swanson River Unit - 2 wells Soldotna Creek Unit - 1 well Fora approved. Budget Bureau bio. 1004--01 Expires. August 31, 1985 6. Ir IMDIAM, ALL~TTBm OB TRIBB MAidS ?. tIMr~ &,0UURMBMT NAldI Swanson River Unit, s. ,Lt~ om ~s.&mm M.&~m MO. 10. I'ZBLD ,&ND POOL; OR WILD~AT Swanson River Field 14. PaR&itT NO. 115. IilVATION! (Show wheib~r Df, ~r, em. eM.) xe. Ch~k Appropriate []ox To Indicate Mature of Notice, Report, or Ogmr Data ~lVl! OI &mm~ Sec. 33, T8N, R9W, and Sec. 4~ T7N~ R9W Kenai Alaska NO'TICB Of INTBNTION 'LO: IUBIBqUBHT ~ OB': SHOOT om ACXDIZB ABANDON'j 8BOOTING REPAIR WELL CHANGE PLANS (Other) ..... [ (No~B: Report results of muir(plo completion on Wdl (Other) X Pressure Test I Completion or ReeompleUon Report and L,oi[ form.) D~S('RIUE PROPOSED OR COMPLETED OPERATION,e. (Clearly state all pertinent details, and ~tve pertinent dates, tneludtnw estimated date of afl,flaw any proposed work. I! well i~ dirmctionMl~ drilled. ~ive subsurface Ioe~tlons and measured and true vertical depths for all markers &a~ tomes perti- nent tO this worK) ~ The AOGCC has issued Area Injection Order No. 13, applicable to Swanson River Field, effective March 16, 1987. In order to comply with Rule No. 6 which pertains to the demonstration of mechanical integrity in the tubing/production casing annulus, the production casing annul( in the SRU 31-33WD, SRU 32-33WD, and SCU 43-4WD will be pressure tested to 1500 psi. The attached procedures outline the steps that will be taken to conduct the test. The pressure testing is expected to be completed by the end of October, .1987. lS. [ hereby certify tiLl. t, the forego~z{g is tr'de/~d correct 3XGNED / , --~ RECEIVED Division of Mine;-a: ,.s urce~OV i 0 1987 ~j~.~ a ..... .. Alaska Oil & Gas Cons. Commission U.S. [,c~,r,men/ of the ~nferior Bureau o: .~. ~ :;.':,:,~e:'. ent , Rea(anal EnKineer :.;', ,.,.,, :", ...:. SI g~,~ ~ DIVISION OF MINi~R~L APPROVED BT ~fl ~,i~l aL- TI~L~ '~. ~PROV~' ~UBIgCT TO THE ~TA~TI~ED BE~UZ~EMENTS *~ In--on, on R~ OCT 0 7 1987 Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or alency of the United States an)' false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. SRU 31-33WD Pressure Test Production Casing PROCEDURE 1. Record pressures on the robing and production casing. The surface casing is cemented. 2. Shoot fluid level in the PC for pump-in volumetrics (8/5/87: FL--O' at 0 psi). 3. If necessary, load the PC with lease crude. Do not exceed 2000 psi surface pressure during pump-in. Monitor all pressures. NOTE: 48 hours prior to initiating pressure testing procedure, conlact the AOC~C at 279-1433 and the BLM at 267-1240, and inform them that a pressure test will be conducted ns per Rule 6 of Swnnson River Field Area Injection Order No. 13, Install two pen recorder to monitor tubing and PC pressmes during the test. Pressure production casing to 1500 psi with lease water. Hold for 30 minutes, noting initial and f'mal pressures on PC and tubing. 5. The pressure test was successf~ if the prodcution casing pressure did not decre, a~ mm than 150 psi (10%) over 30 minutes. If successful, return to injection. ARCO Almlm Inc. II a midilq o~ Atlantic RlchfllM ~ AR38-~001-A 4111' 411t' -- Iql'/' - 2015/ Iit! llll 1114, IIII T,O. ~411' 4- V~" N/It r~oo~C. F-'.f l~A~<~. PAclc~R. Oil & Gas Cons. CommissioI"~, SRU ' $1 - :5:5 W.-O. C&$1NG & TUBING O~:TAIL SE:CTION 33, T. Illq R. IW. SRU 32-33WD Pressure Test Production Casing PROCEDURE 1. Record pressures on the tubing and production casing. The surface casing is cemented. 2. Shoot fluid level in the PC for pump-in volumetrics (8/5/87: FL=O' at 0 psi). 3. If necessary, load the PC with lease crude. Do not exce_~J 1000 psi surface pressure during pump-in. Monitor all pr~ssu~s. NOTE: 48 hours prior to ini6nting pressure testing procedure, contact the AOGCC at 279-1433 and the BLM at 267-1240, and inform them that a pressure test will be conducted as per Rule 6 of Swanson River Field Area Injection Order No. 13. Install two pen recorder to monitor the PC and robing pressures during the test. Pressure production casing to 1500 psi with lease water. Hold for 30 minutes, noting initial and final pressux~ on PC and tubing. 6. The pressure test was successful if the production casing pressure did not decrease more than 150 psi (1095) over 30 minutes. If successful, return to injection. ARCO Alarm Inc. I~ a mk~l~y o~ Atl~'~tlc Rlct'~ C.,om~y AR3B-~3OI-& 'm: ** ,,oo' : I I '"" TOP PLUG 2450' T.O. 2S20' WOmcOvER SCU 43.4WD Pressure Test Production Casing PROCEDUR~ 1. Record pressm~ on the tubing, production casing, and surface casing. 2. Blow down the SC, recording all pressures. 3. Shoot fluid level in the SC for pump-in volumetrics (8/5/87: ~3' at 0 psi; annular volume~.0464 bbls/ft). . Load the SC with lease water containing 10 gal/1000 gal WT 676 corrosion inhibitor and a $ bbl crude cap. If fluid level is the same then 19 bbls is required to f'tH the SC annuius. Do not exceed 300 psi surface pressure during pump-in. Monitor all pressure~. Shoot fluid level in the PC for pump-in volumetrics (8/5/87: FL=O' at 0 psi). If necessary, load the PC with lease crude. Do not exce_~ 2000 psi surface pres~ during pump-in. Monitor all pressures. NOTE: 48 hours prior to initiating pressure testing procedure, contact the AOC~C at 279-1433 and the BLM at 267-1240, and inform them that a pressure test will be conducted as per Rule 6 of Swanson River Field Area Injection Order No. 13. NOTE: During pressure tests of the tubing, closely monitor PC/SC packoff to insure no communication to the surface casing. If any communication is noted, cease pressure test and notify Anchorage. e Pressure test PC/SC packoff to 3000 psi. Install two pen recorder to monitor the PC and tubing pressures during the test. Pressure production casing to 1500 psi with lease water. Hold for 30 minutes, noting initial and final pressures on PC and tubing. 9. The pressure test was successful if the production casing pressure did not decrease more than 150 psi (10%) over 30 minutes. If successful, return to injection. <. ARco AIIska Inc. la a mldiary o~ Atllntk: Rlchlleld ~ AR31~I-A L ! GL. · 139' ORIGINAL K.B. · 15 4 2 ~' OTIS 'S" NIPPLE, POSITION I 3030' 3100' 4911' 5207' PBTD BRIDGE PLUG TO · 6660' ~ L £ 7o,~ I- ~I CHEVRON U.~4 SCU 43-4 a~ TUBING O SECTION 4, TTN~ RgW~ S. SWAN$~ RIVER F; DISPO~L WELt REQUIREMENTS WELL NOS. SRU 31-33WD SRU 32-33WD SCU 43-4WD 1. Follow the procedures outlined in the approved Sundry Notice for well Nos. SRU 31-33WD, SRU 32-33WD, AND SCU 43-4WD. 2. Notify the Chief, Branch of Lease Operations, 48 hours prior to initiating the operations. PHONE: 267-1220 (office) 248-3010 or 344-0336 (after hours) OFFICE HOURS: 7:30 a.m. to 4:00 p.m., M-F, except holidays 3. Submit a revised Sundry Notice for approval prior to deviating from this approved plan. 4. Undesirable events are subject to the requirements of NTL-3A. 5. Ail activity shall take place within the confines of the perimeter of the existing pad. Any required activity off the pad will require prior approval by the Fish and Wildlife Service - Kenai Refuge Manager. 6. Any solid and/or liquid wastes resulting from the proposed activity shall be properly disposed of in an approved disposal facility within the field. 7. Within 30 days of completing the approved plan, please submit the results of the pressure tests on form No. 3160-5. STATE Of ALASKAjI AlA~.,A OIL AND GAS CONSERVATION COl~ .... ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ,.'q Operation Shutdown [] Re-enter suspended well [] Alter casing ~ Time extension ~ Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate C2 Other 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360 Anchorage, AK 99510 4. Location of wellatsurface Sec. 33, T8N, R9W, and Sec. 4, T7N, R9W At top of productive interval At effective depth At total depth Swanson River Unit - 2 wells Soldotna Creek Unit - 1 well 5. Datum elevation (DF or KB) feet 6. ~lnit or Property name ~wanson River Unit $o!do_~-.a Creak Unit 7. Well number SRU 32-33WD, SRU 31-33WD~ SCU 43-4WD 8. Permit number 9. APl number 133-10164-r~0 50-- 13:3-20336-00~ 133-10111- 10. Pool Swanson River 11. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical depth he AO~gC~bas ~su~ Arga IDjeCtion Order No. 13 .applic~ble.gp Swanson iver ~mei~, ezzecnmve march 16, I~87. In order'lo comp±y wznn Rule No. 6 which pertains to the demonstration of mechanical integrity in the tubing/production casing annulus, the production casing annuli in the SRU 31-33WD, SRU 32-33WD, and SCU 43-4WD will be pressure tested to 1500 psi. The attached procedures outline the steps that will be taken to conduct the test. measured The pressure testing is expected to be completed by the end. of true vertical October, 1987. RECEIVED Tubing (size, grade and measured dePth) Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal [] ........ . i987 Alast~a 0~ & Gas Cons. Commission Detailed operations program [] BOP sketch ~ 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is.true and correct to the best of my knowledge i Signed ~,¢_._~-k,,. T~tle Regional Engineer Commission Use Only Date ]0 Conditions of approval Approved by ,.~,., :: ..... Form 10-403 Re~'12-'T'85'"' Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ',;;,~! u r ri.ed _ /o '- /EJJ' 1.. Commissioner J Approval NO. 7- 7.¢'''~'~''- by order of the commission Date/~,' --./"~._~ _~¢/7 Submit in triplicat>, SRU 31-33WD Pressure Test Production Casing PROCEDURE 1. Record pressures on the tubing and production casing. The surface casing is cemented. 2. Shoot fluid level in the PC for pump-in volumetrics (8/5/87: FL=O' at 0 psi). 3. If necessary, load the PC with lease crude. Do not exceed 2000 psi surface pressure during pump-in. Monitor all pressures. NOTE: 48 hours prior to initiating pressure testing Inocedure, contact the AOC~C at 279-1433 and the BLM at 267-1240, and inform them that a pressure test will be conducted as per Rule 6 of Swanson River Field Area Injection Order No. 13. '" . Install two pen recorder to monitor tubing .and PC pressures during the test. Pressure production casing to 1500 psi with lease water. Hold for 30 minutes, noting initial and f'mal pressures on PC and tubing. 5. The pressure test was successful if the prodcution casing pressure did not decreas~ mor~ than 150 psi (10%) over 30 minutes. If successful, return to injection. RECEIVED aas~a 0il & Gas Cons. Commission Anchorar]~ ARCO Ala~l<~ Inc. la a AR38-6001-A HII' r ~ I1~ Il' ,,s: 410' ·- ~" H/Jr (SQOI RECEIVFO Oil & Gas Cons. Commission SRU 31-33 W.-g. CASING 8~ TUBING DE:TAIL SE:CTION $$ T. IN., R. IW. S~ i II ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering COMPANY: ~ ~..~__~ ~ COMPANY' DATE: ,~.~,'~ .-g ? WELL NAME' Transmitted herewith are the following- PLEASE NOTE' BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy OCT 0 2 1967 .... nnm~'fts$~011 Recei pt Acknowledgment' Date' Return Receipt to: ARCO Alaska, Inc. AT.TN: Judy Boegler ATO,- Po~% Office Box 100360 Anchorage, AK 99510 'Fomu ~160--5 (November 1983) (Formerly 9-331) ~ NITED STATES (Oilier iuatz4, DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT PLICATE' SUNDRY NOTICES AND REPORTS ON WELLS (Do not nme this form for propo~ls to drtll or to deepen or plug back to a dlt~etent reservoir. Uae "APPLICATION FOR PERMIT--" for such p~ogmeadL) GAa ~ OTlUl IRR WELL X Water Disposal Wells 2. NAMa OF OPE~ATO~ A~C0 Alaska, Inc. 3, ADD~ta8 OF OPSaATOa Post Office Box 100360 Anchorage, Alaska 99510 LOCATION or Wr. Lr. (Report location clearly and in accordance with any State requirements.· See also space 17 below.) At surface Swanson River Unit - 2 wells Soldotna Creek Unit - 1 well 14. PERMIT NO. I15. EL~VA?IONB (Show' whet, her DF. rr. Form approved. Budget Bureau No. 1004--0135 Expires_ August 31, 1985 §. LaAIB DESIGNATION AND II~l&/- NO. 6. I~ INDIAM. ALLO'TTBB OR TRIBE NAME UNIT AGIBBMaNT NAMa Swanson River Unit, 9. WELL NO. 10. FLUID AND POOL, OI WILl, AT Swanson River Field 11. II~., ~*., I., if., au ILK. ~ aUIVBY OR AR]IA Sec. 33, T8N, R9W, and Sec · 4, T7N, .R9W 12. ~oa,,. o, ,.-.saI ia. KenaiI Alaska 16. Check Appropriate Box To Indicate Nature o1: Notice, Report, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPI.ETE SHOOT OR ACIDIZB ABANDONs REPAIR WELL CHANGE PLANS (Other) X Pressure Test FRACTUaB Ta]BATMBNT . AL~INO ~A/ING SH~TING OR ACIDIZINO ABAN~NMBNTo (Other) , (NoTs: Report results of multiple completion on Well Completion or Reeompletion Report and Log form.) DE.~('RIUg PROt'OSED OR CO.MPLETEO oPEaA'rlo.~s (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionall¥ drilled, ~ive subsurface locations and measured and true vertical depths for all markers and ~one~ perti- nent to this work.) s The AOGCC has issued Area Injection Order No. 13, applicable to Swanson River Field, effective March 16, 1987. In order to comply with Rule No. 6 which pertains to the demonstration of mechanical integrity in the tubing/production casing annulus, the production casing annuli in the SRU 31-33WD, SRU 32-33WD, and SCU 43-4WD will be pressure tested to 1500 psi. The attached procedures outline the steps that will be taken to conduct the test. The pressure testing is expected to be completed by the end of October, 1987. 18. I hereby :~the forego~ is tr'ae/gfld correct Regional Engineer (This space for Federal or State olllee use) APPROVED BY CONDITIONS OF APPROVA3~, IF AI~: TITLE *See InWudions on Reveae Side Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. SRU 31-33WD Pressure Test Production Casing PROCEDURE 1. Record pressures on the tubing and production casing. The surface casing is cemented. 2. Shoot fluid level in the PC for pump-in volumetrics (8/5/87: FL~0' at 0 psi). 3. If necessary, load the PC with lease crude. Do not exceed 2000 psi surface pressure during pump-in. Monitor all pressures. NOTE: 48 hours prior to initiating pressure testing procedure, contact the AOGCC at 279-1433 and the BLM at 267-1240, and inform them that a pressure t~st will be conducted as per Rule 6 of Swanson River Field Area Injection Order No. 13. . Install two pen recorder to monitor tubing and PC pressures during the test. Pressure production casing to 1500 psi with lease water. Hold for 30 minutes, noting initial and final pressures on PC and tubing. 5. The pressure test was successful if the prodcution casing pressure did not decrease more than 150 psi (10%) over 30 minutes. If successful, return to injection. ARCO Alaska Inc. Is a sui~ldlmy of Atlantic Richfield Company AR3B-6OO1-A II II1' 4- ~" H/~ -- Iql'7 - ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering September 2, 1987 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Wondzell- This letter is to inform you of the naming convention for the Swanson River water disposal wells. We will be using these names in future correspondence and notices. The monthly injection report will be reissued from March, 1987 to include information on the disposal wells as you requested through Mr. Ronzio. Wel 1 Name API Number O1 d Name SRU 21-33WD 133-10162 SRU 221-33 SRU 41-33WD 133-10167 SRU 31-33WD 133-20336 SRU 32-33WD 133-10164 SCU 43-4 WD 133-10111 SCU 243-4 If you have any questions, please give me a call at 263-4299. H. F. Blacker Regional Engineer HFB:MLE'ch'O034 cc' Joseph A. Dygas, Bureau of Land Management D. Gann/J. Renfrow SRF J. D. Hales ATO 704 R. H. Larson KI W. M. Peirce ATO 1390 E. A. Raleigh ATO 700 G. S. Ronzio ATO 2020 T. Wellman ATO 1396 RECEIVED SEP o 9 Naska 0il & Gas 13ons. Commlssloff Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany CJi_ STATE OF ALASKA ALASKA AND GAS CONSERVATION C0~. .!SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ~ Water Di,qpo,qal 2. Name of Operator 7. Permit Number Chevron U.S.A. Inc. 80-114 3. Address 8. APl Number P.O. Box 107839, Anchorage, Alaska 99510 5o- 133-20336 4. Location of well at surface 9. Unit or Lease Name 950'S & 1450'W of NE Corner Section 33, T8N, Rgw, S.B.&M. Swanson River Unit At Top Producing Interval 10. Well Number Same SRU 31-33 WD At Total Depth 11. Field and Pool Same Swanson River 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. G.L. = 163' A-028399 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116' No. of Completions 5-20-81 5-24-81 9-23-85 NA feet MSLt 1 17. Total Depth {MD+TVD) 18. Plug Back Depth (MD+TVD} 19. Directional Survey ] 20. Depth where SSSV set 21. Thickness of Permafrost 2461' MD 241Y MD YES [] NO ~[ NA feet MD NA 22. Type Electric or Other Logs Run NA 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 5½" 17# & 20~ N-80' 0 2413' 6-1/8" 100sks"O" , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) · 238Y-2310' 7Y 4 ½" JHPF 2-7/8" 1917' 1917' 2284'-2256' 28' 4 ½" $I-IPF .... 2242'-2162' 80' 4 ½" JHPF 26. NA ACID, FRACTURE, CEMENT SQUEEZE,, ETC. 2140'-2100' : ,., ,,4,,0' 4 ½" JHPF . ... DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED , .. , 221' 884 Holes . ,, ,, : 27. NA PRODUCTION TEST Date First Product on . Method of Operation (Flowing, gas lift, etc.) ,.. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO , ... .~ .~ TEST PERIOD ~ oIL-BBL. GAS-MCF wATER-DEL OIL GRA'VlTY-API (corr) Flow Tubi. ng .,' .Cas.ing Pressure CALCULATED Press.. . .. 24-HOUR RATE'~ ,- , 28. ~TA CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,, "qtas;~a 0il S Gas C0r~s,," ." l0 r'0t?~rrFss" ~ ., Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . 29. 30. NA GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE VERT. DEPTH NA FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS NA 32. Signed I herebycertif' that the foregoing is true and correct to the best of my knowledge Area Operations T~t~e Superintendent INSTRUCTIONS General: This form .is designed f'or submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ( STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION C(~'~MlSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER ~ Water Disposal 2. Name of Operator Chevron U.S.A. Inc. 7. Permit No. 80-114 3. Address 8. APl Number P.O. Box 107839, Anchorage, Alaska 99510 50- 133-20336 4. Location of Well at surface: 950'S & 1450'9/ of NE Corner Section 33, T8N, R9W, S.B.&M. I 6 . Lease Designation and Serial No. A-028399 5. Elevation in feet (indicate KB, DF, etc.) _ G.L. = 163' 12. 9. Unit or Lease Name Swanson River Unit 10. Well Number SRU 31-33WD 11. Field and Pool Swanson River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [~ Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began operations at 12:00 P.M. 9/17/85. Nippled down the tree, and nippled up the BOPE. Tested the BOPE to 3000 PSI. Pulled out of the hole with fiberglass tubing. Picked up and tripped in the hole with 2-7/8" drill pipe and 6-1/8" bit. Attempt to drill up packer. Milled over packer, and pushed packer to 2413'. Set bridge plug at 2020'. Rigged up and ran 54 joints 5½" 17# and 20# N-80 8RD and BTC Sp. Cl. Cplgs set at 2015'. Cemented the 5½" casing back to the surface with 100 sacks Class "G" + 3% CaC12 at 15.8 PPG. WOC. Cut off 5½" casing. Cut off 7" tubing head. Weld on 5½" x 6" - 3000 PSI tubing head. Nippled up BOP's and tested casing to 1000 PSI. Tested BOP's to 3000 PSI. Tripped in the hole with mill, motor, and 2-7/8" drill pipe. Drilled cement 1993'-2018'. Tested the 5½" x 7" annulus to 1000 PSI for 30 minutes. Drilled bridge plug at 2020'. Tripped in the hole to 2413'. Picked up and tripped in the hole with a packer on 2-7/8" tubing. Set packer at 1917'. Ran seal assembly on tubing and tested in the hole to 3000 PSI. Tested the annulus and packer to 1000 PSI for 30 minutes. Nippled down the BOP's and nippled up the tree. Tested the annulus to 1000 PSI for 30 minutes. Operations complete at 12:00 A.M. 9-23-85. RECEIVED h!0v 0 ? 198 Alaska 0il & Gas Cons. C0mmiss~0n 14. I here~ti~t~he/oregoing is true and correct to the best of my knowledge. Area Operations Signed ~ ~~17.~ Title Superintendent The spa~w for Commission use Conditi~Js of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMORANDUM TO: THRU: FROM: State of Alaska ALASKA OIL AND GAS CONSERVATION COPR.iISSION C. V~~_~er ton Chai~7~n ' ?.;/,.":.?./"' Lonnie C. Smith ' ,'"' L;~ ., Co~issioner Ilarold J. Hedlund Senior Petroleum Engineer DATE: FILE NO: September 26, 1985 A. HJH. 4 TELEPHONE NO: SUBJECT: ~'~ech. Integrity Tests Chevron SRU 31-33 WD and 243-4 Permits Nos. 80-114 and 61-029 Swanson River Field Sunday~ September 22, 1985: Harold Scott with EPA and I traveled to"~e~ai'"via AA%"bn"'this date to witness mechanical integrity tests under UIC emergency permits on SRU Wells 31-33 ~ and 243-4. We arrived at the Swanson River Field at 3:40 PM. The drilling crew had run drill pipe to approximately 2400' in well SRU 31-33WD and was circulating water to clean up the wellbore when we arrived. We were informed that testing would be delayed to at least 5:00 AM in the morning and that testing of SRU 243-4 would commence at 10:00 Monday, September 23, 1985: Well SRU 31-33WD was not ready for testing at I0.00 AM so Well SRU 243-4 was tested first. At 10:10 AM, the annulus was pressured up to 1000 psi.. :The pressure held for thirty minutes as required. Witnesses to this test were Harold Scott with EPA, Joe Russell with BLM, J.B. Logan with Chevron and myself. As soon as the test on SRU 243-4 was completed, we traveled back to SRU 31-33WD. The drilling crew had pressured up the annulus to about 800 psi about twenty minutes before we arrived. After our arrival the pressure was increased, to 1075 psi. The pressure held for thirty minutes as required. Witnesses to this test were Harold Scott, Joe Russell, Dave Renshaw With Chevron and myself. In summary, I witnessed successful mechanical ~integrity tests on SRU 243-4 and SRU 31-33WD. 02-00IA(Rev. 10/79) ~ , Chevron Chevron U.S.A. Inc. P.O. 8ox 107839, Anchorage, AK: 99510 · Phone (907) 786-6600 J.L. Weaver Area 0peratmns Superimenden.', Productmn 0epartmem September 17, 1985 Remedial Action SRU 31-33 WD Swanson River Field~ Alaska U.S. Environmental Protection Agency Region 10 Attn.. Mail Stop 409 1200 Sixth Avenue Seattle, Washington 98101 Dear Sirs: In response to your letter dated 8/30/85 regarding the mechanical integrity test on SRU 31-33 WD, Swanson River Field, Chevron U.S.A. submits the following plan of action for the subject well. We propose installing a protective string of casing from the surface to a depth of +2000'. This casing string will be cemented to surface and a new tubing string run t-o the existing packer at 2050'. The annulus between the tubing and new casing will then be pressure tested as per the permit conditions. The proposed workover program along with a proposed tubing detail is attached for your information. At this time, we plan on the work starting the week of September 17, 1985. The EPA will be notified as to the timing of the integrity test of the casing-tubing annulus at the completion of this work. The well is currently shut in. The tubing, casing pressure, and the annulus fluid level were being monitored daily when the well was injecting, as per the conditions of your letter dated 8/30/85. This data was being recorded daily and is available for inspection through our office. We also plan. on retesting SCU 243-4, as per telecon with Harold Scott of your office, during the same time period. If there are any questions concerning this plan or the well status, please contact Mr. J. B. Logan at (907)786-6738. JBL:mw Attachments ~Very sineerely yours, / / J. L. Weaver ..... ~ v,~ a tJa5 OO,qS. CO~I~JSSJOi3 AaChorage U.S. Environmental Protection Agency Septembe~r 1.7, 1985 Page 2 Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr., Anchorage, AK 99501 ARCO Alaska, Inc. P.O. Box 100360, Anchorage, AK 99510 Marathon Oil Co. P.O. Box 2380, Anchorage, AK 99510 Union Oil Co. of California P.O. Box 6247, Anchorage, AK 99502 Bureau of Land Management Branch of Solids & Fluids 4700 East 72nd Ave., Anchorage, AK 99507 <(O STATE OF ALASKA ,<' ALASKA IL AND GAS CONSERVATION CC~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator Chevron U.S.A. Inc. OTHERX] Water Disposal 7. Permit No. 80-114 3. Address 8. APl Number P.O. Box 107839, Anchorage, AK 99510 5o- 133-20336 4. Location of Well at Surface: 950'S & 1450'W of NE Corner Sec. 33, T8N, RgW, S.B.&M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. G.L.: 16Y A-028399 12. 9. Unit or Lease Name Swanson River Unit 10. Well Number SRU 31-33WD 11. Field and Pool Swanson River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing ~]~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well ~ Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. 14. I hereby certi~e and correct to the best of my knowledge. Signed / ~t-/[~7~-]r-~-~._~ Title Area Engineer The space below for Commission use Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). A recent pressure test of the tubing-casing annulus showed that the annulus would not hold pressure. This puts this well in noncompliance of the UIC permit issued June 1985. The EPA requested that we bring the well into compliance or abandon the well. We intend to do the following: 1. Shut in offset injection wells that may be injecting into the same interval. 2. Move in and rig up a workover rig. 3. Kill the well as required. 4/asl~a 0i~ ':;r ~'~'~' . 4. Nipple down the tree and nipple up a 3000 PSI annular BOP. 5. Pull out of the hole with the 3½" tubing. 6. Clean out to .PBTD of~with a bit. 2~~,, 7~e~' ' 7. Run 200fi+ of 5½" OD 17# and 20# N-80 or better grade special clearance casing. 8. Cement the casing back to the surface with 175 sks of Class "G" cement at 15.8 PPG. 9. Cut off the 7" casing. Cut off the 5½" casing. Nipple up the 5½" SOW X 6" 3000 PSI tubing spool. Nipple up the 3000 PSI annular BOP. 10. Clean out to t,,,, v~, --, 2050. 7,0 ail P''''~xcS" ~ ¢ % 11. Inject into.,well to make sure that.,the ~.~.~.,e, .~_opeB, _~, /~5. 12. If the ~ ~s not open, the ~r.w-dl-tre-'~h°h~ a new packer will be set at 1950'. 13. Run new 2-7/8" 6.5# N-80 8RD EUE tubing and space out. 14. Test the annulus and packer to 1000 PSI. 15. Rig down the rig and move off the rig. Date 'Conditions of Approval, if any: Approved by COMM ISS ION ER Form 10-403 Rev, 7-1-80 Approvod Co~¥ P,~turr~ By Order of the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate WELL' CHEVRON U.S.A. INC. WESTERN REGION _ ALASKA AREA WELLWCRK ~DURE ~UMMARY 3( aw'o ,~"~~/-~- . TYPE WELL' TYPE JOB: LOC.' SUPPLEMENTAL SUMMARY E] NO. WELL DATA' K,B. CASING' LINER ' T.D. ~ ~ / PBTO E. ~/'J?-) ¢ ~Y¥/' TUBING ' PERFORATIONS ' NOTES: PROGRAM ! ','-"Z"PS', DETAILS ATTACHED 0 RECEi'VED Distribution: o.~.o, ,o w.,, ~,,.SEPt !.:~ 1§85 Orig. Superintendent Engr. (3) Field Office (I) Alaska Oil & Gas Corm. Commission ~repore~ (I) Anchorac~e Engr. Technicten (I) CHEVRON U.S.A. INC. WESTERN REGION ALASKA A.qEA WELi..,W(~ pROCEC~JRE SUMMARY OF CONTINUED): :eYe.," ~r)~=/V-fi"<::) .Tg?z/';Ac~ fJ~rt¢ i?J'- 54 c~<s DETAILS ATTACHED RECEIVED Olstrl butloft: Original to Well File Orig. Superintendent E:ngr. Field Office Engr, l'e¢~nielon [I ) Alaska. Oi~ & Gas Cons. Oommissior;.N~pt.°ved ,p,I,,,h( Date · _ i CHEVRON U.S,A. {NC, WESTERN REG)ON ALASKA AREA WELLWORK PFC, DURE ~U, MMAF~y _ CONTINUED): OF' , i DETAILS ATTACHED , iii ii i ~! i i i i iii i llj ...... ii iii lji ii · i i i i m iii J i i i i ii i i i I I i i i · i ii I i Distribution Date .--- , ,) TYPE A2 TUBLNG HANGER 3~z'' I01° $~' ~?(' 425' 430' J.P. 4- ~'l" Hit (SQl:l} 2, 7/8" Tubing 1/2 Caalng ' (Protective itrlng cemented in piece) ZlOO Z~ZO ZI40 · I ZIIZ : zzl4 · 2313' · approx. 2000' ZO~O'------ MOOEL F,I BAKER PACKER W/SEAL ASSLY. * (WIRE LINE mEASUREmENT) (Tubing end teeing alzee and welghte may change pending lvlileblllty). WORKOVER 9'8-81 PROPOSED DETAIL I I SRU - w:O. CASING & TUBING DETAIL SECTION 33 T. 8N., R.9W. SM CHEVRON U.S.A. I~C. COMPLETION REPORT- REMEDIAL AREA: Swanson River Field Kanai Peninsula, Alaska PROPERTY: Swanson River Unit WELL NO: SRU 31-33 WD LOCATION AT SURFACE: LAND OFFICE: Anchorage LEASE NO: A-028399 API NO: 50-133-20336 961' South and 1386' West from NE C~rner Section 33 T8N, R9W, S~. LOCATION AT TOTAL DEPTH: ELEVATION: 165' GL DATE: Sam~ BY:~' T.L. AREA SUPERVISOR DATE COMMENCED REMEDIAL WORK: DATE COMPLETED REMEDIAL WORK: RETURNED TO PRODUCTION: N/A July 5, 1981 September 4, 1981 TOTAL DEPTH: 2461' EFFECTIVE DEPTH: 2406' CASING: 10 3/4" Conductor at 80' 7" Cemented at 2461' SUMMARY PLUGS: ~uly 5~ 1981 Moved in with Gearhart Industries, Inc. Wireline Service and prepared to run differential temperature log. July 6~ 1981 Gearhart ran a borehole audio tracer survey from 200' to 2408' and differential temperature log from 50' to 2408'. July 10, 1981 Rigged up Gearhart and ran a cement bond log with Gamma Ray/Neutron and Seismic Spectrum from 52' to 2408' with second run Cement Bond Log with Gamma Ray/Neutron from 52' to 2408' then moved off location. Shut well in. August 10, 1981 Rigged up Tolloff Construction crane contracted to R. L.'s Oilfield Service with tubing handling tools. Ran into hole with Baker 47B Model "C" retrievable bridge plug on 2 7/8" tubing. Set plug at 474' and pulled out of hole. Dumped nine sacks of sand down 7" casing. Landed on bridge plug at 474'. A~t 11, 1981 Made up Gearhart perforating tool with 4" H.S.C. using DML 23 charges, jet perforated 4 ½" holes from 424' to 425' and pulled out. Well began to flow fresh water from down hole. Rigged up and pumped 46 barrels of 11.1 ppg mud down hole. Unable to stop water flow. Pumped another 40 barrels of 12.1 ppg mud down hole and killed well. Gas coming out of the 7" x 10 3/4" annulus. Pulled out of hole and rigged up Baker 478 Model C full bore retrievamatic cementer on 2 7/8" tubing. Set packer at 332'. Mixed 75 sacks of Class "G" cement with 3/4% D-31 and 15 gallons D-45L (B.J. Hughes) with pressure at 500 psi slowing to 200 psi. Displaced hole with four barrels of mud with pressure holding at 200 psi, Was unable to stop small gas leak. A~t 12, 1981 Waited on cement 12 hrs. Gas still leaking around surface pipe. Pulled packer out of hole. Made up 6" bit, dyna drill, and drill collars on 2 7/8" tubing. Ran into hole and tagged cement at 335'. Drilled stringers and hard cement to 425' circulating sand out from 425' to 470'. Pulled out of hole. Ran in hole with retrieving head and retrieved bridge plug at 474'. Aui~ust 13, 1981 Gas still coming out of the 7" x 10 3/4" annulus. Ran in hole with open ended 2 7/8" tubing. Broke down perfs (424' to 425') using water at 1500 psi. Pumped ½ bbl. at 4 BPM and 600 psi. Rigged down. Flowed well back, Will flow back until pressure is zero. Moved crane to SRU 32-33. August 21~ 1981 Rigged crane back up on hole. Nippled up B. J. Hughes and killed well with 11.2 ppg mud. Pulled 15 joints of 2 7/8" tubing, picked up Baker Model C bridge plug, ran in hole and set at 474'. Pulled out of hole with tubing, spotted eight sacks of sand on bridge pl{~g. R/U B. J. Hughes and squeezed perfs 425' - 426' with 50 SX of Class "G" with 2% CaC12, 3/4% D31, and 15 gal. R-45-L. Displaced with mud. No squeeze pressure seen. Shut well in. WOC. Aul~ust 22~ 1981 Shut in - WOC. August 23, 1981 Ran in hole with 6" bit, dyna drill, and drill collars on 2 7/8" tubing. Plugged bit with cement, pulled out of hole. Cleaned bit. Ran in hole with 6" bit, plugged bit again, pulled out of hole and cleaned bit. Au~mst 2¢, 1981 Ran in hole with 6" bit, dyna drill, and drill collars; drilled 6' of hard cement down to 426'. Pulled out of hole, rigged up Gearhart, and perforated 4 CJPF at 370'- 371' using 4" HSC with DML 23 charge. Rigged up Halliburton and cement squeezed perts 370'- 371' with 60 SXS of Class "G" with 2% CaC12, 0.5% Halad 4, and 0.5% CFR-2. Squeeze was successful. Shut in and waited on cement. August 25, 26, 1981 Gas no longer coming out of 7" x 10 3/4" annulus. Picked up 6" bit, dyna drill, and drill collars. Ran in hole on 2 7/8" tbg. and drilled out hard cement. Pulled out of hole and made casing scraper clean out run. Ran in and retrieved bridge plug. Rigged up Gearhart and perforated 4 CJPF using a 4" HSC gun the. following intervals.* 2383' - 2313', 2284' - 2256', 2242' - 2162', and 2140' - 2100' (884 holes)=-' Gas started coming out' between the 7" x 10 3/4" annulus and the 10 3/4" x conductor. Ran in and set 7" Baker bridge plug at 474'. Rigged up Gearhart and perforated 429' - 430' (4 holes) using a 4" HSC casing gun. August 27, 1981 Killed well with 10.6 ppg mud using Halliburton. Braden head squeezed perfs 429'- 430' with Halliburton using 43 SX of Class "G" with 0.5% Halad 4, 0.5% CFR-2, 2% CaC12 (1.15 cu. ft/sk yield, 15.8 ppg). No squeeze pressure seen, shut well in, and WOC. August 28~ 1981 Picked up 6" bit, dyna drill and drill collars. Ran in hole and drilled out cement. Pressure tested squeeze, squeeze would not hold. Ran in hole open ended. Rigged up' Halliburton and squeezed perfs 429' - 430' using 43 SXS of Class "G" with 0.5% Halad 4, 0.5% CFR-2, and 2% CaC12 (1.15 ft3/SX.yield, 15.8 ppg). No squeeze pressure seen, over displaced perfs, and resqueezed using 43 SX of same cement. No squeeze, over displaced cement. August 29~ 1981 Resqueezed perfs 429' - 430' with Halliburton using 75 SX of Class "G" with 0.5% Halad 4, 0.5% CFR-2, and 2% CaC12 (1.15 ft3/SX yield 15.8 ppg). Staged cement into perfs for a 1.50 psi pressure increase. Shut well in and WOC. August 30, 1981 W.O.C. August 31, 1981 Gas still coming out of annulus. POOH with 2 7/8" tubing. RIH with 6" bit, dyna drill and drill collars and drilled out hard cement. Rigged up Gearhart and perforated 380' - 381' (4 holes) with 4" casing gun. RIH with open ended 2 7/8" tubing. Rigged up Halliburton and squeezed perfs 380' - 381' with 50 SX of Class "G" cement with 0.5% Halad 4, 0.5% CFR-2, and 2% CaC12. No squeeze, overdisplaced hole. September 1, 1981 R/U Halliburton and squeezed perfs 380' - 381' using 119 SX of Class "G" cement with 0.5% Halad 4, 0.5% CFR-2, and 2% CaC12. Staged in cement. WOC. September 2, 1981 Pulled tubing. RIH with 6" bit, dyna drill, and drill collars, and drilled out cement to 373'. Gas still coming out the annulus. Broke down perfs 370' - 371' with 1100 psi. Rigged up Halliburton and squeezed with 80 SX of Class "G" cement with 0.5% Halad 4, 0.5% CFR-2, and 2% CaC12. (1.15 ft3/SX, 15.8 ppg) to 350 psi final pressure. Shut in - WOC. September 3, 1981 Gas still coming out annulus. RIH with 6" bit, dynadrill, and drill collars. Drilled out cement to 325'. R/U Gearhart and perfd 320'- 321' (4 holes). R/U Halliburton and squeezed perfs 320' - 321' with 43 SX of Class "G" cement with 0.5% Halad 4, 0.5% CFR-2, and 2% CaC12 to 250 psi. Over displaced perfs, resqueezed with 50 SX of same cement to a final pressure of 400 psi. September 4, 1981 Gas still coming out of annulus. Drilled out cement to 300'. R/U Gearhart and perforated 100' - 101' (4 holes). R/U Halliburton and squeezed perfs 100' - 101' with 108 SX of Class "G" cement with 0.5% Halad 4, 0.5% CFR-2, and 2% CaC12. Had cement returns to surface out of the 7" x 10 3/4" annulus. September 5, 1981 Shut down. September 6, ?~ 8~ 1981 No gas coming out of the 7" x 10 3/4" annulus or the 10 3/4" x conductor. Drilled out cement plug down to the bridge plug at 474'. Pressure tested casing to 300 psi for 15 minutes - held o.k. Pulled bridge plug. Made 7" casing scraper run to 2383'. Set Baker 7" Mbdel FI retainer production packer (413-06-8540) at 2050' with Gearhart. Ran 33" (3.71" OD, 3.02" ID), 2000# W.P. Star Fiberglass HP EUE 8rd tubing with Baker packer anchor. Latched into packer at 2050' and landed tubing in 6000 lbs. tension (16" stretch tensile strength 20,000 lbs.). Nippled up tree and turned well over to the production foreman. Well Name:L JF f'{ J/'33aff) PERFORATING DETAIL Page -----__ of Odometer Zeroed On Correlations: Electric Log Carrna Log Correction Depth Depth Perforating: Run #__/ Electric Odometer Log Collars Collars Reset Odometer from and perforated ~Jf3 ' ..... · Distance From Collar Locator To Top Shot_ Electric Log d~'~'~D~h C~ f{~~h Correction Run # L_ Electric Odometer' Log Collars Collars ~C . _ L,,~ ..... R~set Odometer from ~7~~ to~ ~,~ ...... Run # Electric Odometer Log Collars Collars Reset Odometer from and perforated 23~Z ' to ~2 Perforating: Run .# Electric Odometer Lo~ Cc liars Collars 2_ s 3o ~ 23 z~f .... Reset Odometer from 2~.f' to23 I0.~' and perforated ~323 ' to 23/3* ' with Run # ~ Electric , Odometer Log Collars Collars _ 23Z~ , ,..c '.;.'" :. ,-' z~q~ ' Reset Odometer ~%f4.ff' to ~L&/.f ' and perforate'd 2~F , to ~25g ' wi~h ~3N~ Run # Electric Odometer Log Collars Collars -. Reset Odometer from and perforated ~Z~ ' ,, tO 22f~ ' with ,, ~ ,, ,,,, ,, Note: Please use the reverse side of this form to record details of the perfora, ting gun. Correlations Performed by Perforating Witnessed by Ppc~-'~ 57 (CD- 6-74) Well Name: Field: ~.~._. PERFORATING DETAIL Date: Page _of Odometer Zeroed On o Correlations: Electric Log Gam~na Log Correction Depth Depth Perforating: Run # ~ Electric Odometer Log Collars Collars Reset Odometer from and perforated ~M~ ' to 22Zz ' with ~z//~r , ,, Pe rfora ting: Run. # __/ Electric Odometer LoB, Collars Collars , ,, ,,~ Reset Odometer from and perforated 2/F~ ' to ~/& ~' with . Distance From Collar Locator To Top Shot Electric Log Gamma Log Correction Depth Depth : Run #. Electric Odometer' Log Collars Collars , ,, Reset Odometer from Rlgg.f' to zlqq. and perforated to zb~ Run # Electric Odometer Log Collars Collars Z z. SZ 2. Reset Odometer from and pe~forated ~Co~ ' ,, Run # Electric Odometer Log Collars Collars z-z-"bz'- ~ ~Z2"~ -5, Z_zl/.5'- ~109 Reset Odometer and p~rforated ~3 ' to 2/~0' with tRun # ,, Electric Odometer Log Collars Collars _ ~/I/. ~ Reset Odometer from ~q~ ' to 2~¢~, and perforated 2_/~0' to 2lo# ' with Note: Please use the reverse side of this form to 'record details of the perfora, ting gun. Correlations Perfor~..ed by /~~ Perforating Witnessed by _~F~'/~,., .. PR0-352 (CD-6-74) Swanson River Waste Water Injection Wells Radioactive Tracer (Migration) Surveys SRU 31-33WD Date of survey: 11-09-85 Tubing Pressure: 750 psi Casing Pressure: N/A Detail: Ran it~ hole and tagged bottom at 2397'. Pulled up to 2090' and released a radioactive (R/A) slug. Waited 20 minutes and the slug was not seen, therefore no fluid movement was detected past the tool outside the casing. Injection rate at this time was approximately 4440 BWPD. The tools were then pulled up to 2040' 8,1ad another F~/A slug was released. After 20 minutes it was noted that the tracer hsd t3ot passed the tool, therefore there was no fluid movement past the packer into the tubing casir, g annulus. Injection rate at this time was approximately 4090 BWPD. Finally the tools were pulled up to a depth of 50' &nd a R/A slug i-eleased, t'4o fluid movement was detected past the tools outside the tubing. The i;~jection rate at this time was approximately 4490 BWPD. Results: No ftuid movement outside the casing or tubing annulus was observed during injection. SRU 32-33WD Date of survey: 11-08-85 Tubing Pressure: 850 psi Casing Pressure: N/A Detail: Ran in hole and tagged bottom at 2372' Pulled up to 2090' al~d released a R/A ~lug. Did not detect &tly fluid movement up casing after 15 minutes. Pulled up to 2040" ~nd released a R/A slug. Did not detect any fluid movement after 20 minutes. Injection rate for both tests was approximately 800 BWPD. Finally pulled L,.p to 50' and released an R/A slug. No fluid movement was detected past tools. Injection rate was .approximately 800 BWPD. Results: No fluid movement outside the casing or tubing annulus was observed durir~g injectiol~. SRU.. ~' 1-:33WD Date cf survey: 11-07-85 Tubing Pressure: 800 psi Casing Pressure: 50 psi Detail: R;,n iF, ho!e and tagged bottom at 2118'. Pulled up to 2092' and released Pt/A slug. No fluid movement detected past tool outside casing after 12 minutes. Pulled up to 20,53' and released slug, no fluid detected, then pulled up to 1749' and released P,/A slug. No fluid was detected moving pas'[ tools outside casing and tubing. Finally pulled up to 50' and repeated test with the same results. The injection rate for all the tests was approximately 1500 BWPD. Results: No fluid movement outside the casing or tubing annulus was observed during injection. SRU 41-33WD Date of survey: 11-09-85 Tubing Pressure: 900 psi Casing Pressure: N/A Detail: Rail in hole to 2872' and released R/A slug. Did not detect any fluid movement past the tools after 45 minutes, injection rate was only 36 BWPD. Pulled up to 2697 a~d repeated test, no fluid movement detected after 45 minutes. Pulled up to 50' and repeated test with the same results. The injection rate t-emanied at approximately :'-',6BWPD. Results: No fluid movement outside the casing or tubing annulus was observed during injection. Chevron Chevron U.S.A. Inc. P.O. Box 107839, Anchorage, AK 99510 · Phone (907) 786-6600 J.L. Weaver Area 0pera.ons Supe.ntendenl Production Oepartmenl August 15, 1985 Integrity Tests SRU 31-33 W.D. and SRU 32-33 W.D. Swanson River Field~ Alaska U.S. Environmental Protection Agency Region 10 Attn: Mail Stop 409 1200 Sixth Avenue Seattle, Washington 98101 Dear Sirs: Please find attached the results of the pressure integrity tests on the Swanson River Water Disposal Wells SRU 31-33 W.D. and SRU 32-33 W.D. This includes a summary of each test and a copy of the pressure chart recorder. These tests were performed on August 6, 1985 and were witnessed by the following people: Name Harold Hedland Debra Gates Jerry Opatz Joe Dygas Joe Russell Dan Marlowe Bud Kloppenburg Jim Logan AOGcCOrganizati°n EPA EPA Chevron USA Chevron USA Chevron USA The pressure test on SRU 32-33 W.D., whieh was recently worked over, was successful. The casing annulus held a pressure of 950 psig for over 30 minutes. Due to the type of pump being used for the test, we were unable to achieve 1000 psig exactly. However, since the test pressure of 950 psig is higher than the normal operating pressure of 800-850 psig, it was accepted by the EPA representa- tives on site. The pressure test on SRU 31-33 W.D. was not successful as the easing annulus would not hold pressure.. We believe that this was due to cement squeeze holes in the casing which are not sealing. These holes, which range in depth from 100' to 430', were originally shot for cement squeeze work to isolate shallow gas zones. A copy of the casing and tubing detail, along with the completion report showing the cementing detail, are shown in Attachment #1. The depth of these holes and the U.S. Environmental Protection Agency August 15, 1985 Page 2 type of formations behind the casing make it difficult to repair these holes to where they are a pressure seal. This does not, however, affect the integrity of the well. The radioactive survey completed in 1983 and the fact that there is a pressure differential of 850 psig between the tubing and the casing indicate that the well is in sound condition. A copy of the radioactive tracer survey for this well is also shown in Attachment #1. Daily monitoring of the casing and tubing pressure along with the injection rate will flag any deviation from the current condition of the well. Consequently, if any abnormality is noted, the well will be shut in and the problem located. At that time, it would then be determined if remedial action is necessary. In addition, the governing agency would be informed as per the permit conditions. If there are any questions concerning these tests, please contact our representa- tives in Anchorage, either Christine D. Creed or James B. Logan at (907)786-6600. :JBL:mw Attachments ~rs, /J. L. Weaver cC: Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SRU ATTACHMENT ~ 1 31-33 INTEGRITY TEST SWANSON RIVER FIELD Tubing Casing INIT Pressure: Pressure: IAL CONDITIONS 860 ps~g (Wet I Inject,rig) 0 ps~g (Annulus ful I ) Start pressur ~ng annu at 10:50 A.M. on 8-6.-- annulus valve. Annulu Elapse P lus us 85. Pr s pres d T i m e 2 min. 3 min 5 IBI ri 6 m~n 7 mia 8 9 rni n 10 rni RESSURE TEST ~ng Sal tz pump truck and essured to 300 psig and sure dropped to 10 psig n . Pressure (psig) 150 100 95 90 85 80 75 70 lease water shut in as follows: Test cornpleted at I i :00 A.M. and equipment r igged down. Annulus pressure test unsuccessful . RECEtVED ,Alaska 0il & Gas Corts.{'.o~tmlssJo~- Anchora~s MEMORAr UM Stat of Alaska TO: THRU: FROM: Lonnie C. Smith ,'" Commissioner Harold J. Hedlund Senior Petroleum Engineer ALASK~OI~ A~]D GAS CONSERVATION COM~IISSION C~%.~C~/./~¢,~erton ~'~: August 12, 1985 . Fie18. Tuesday, August 6, 1985: I witnessed mechanical integrity tests on two wells for which UIC Emergency Permit Numbers AK-2D0098-E and AK-2D0099-E have been issued. Other witnesses of these tests included.Deborah Gates and Jerry Opatz with EPA, Joseph Dygas and Joseph Russell with BLM and H.G. Kloppenburg and J.B.. Logan with Chevron. The first well to be tested was SRU 31-33 WD. Water was being. injected through fiberglass tubing set in a packer. Tubing pressure was 730 PSI with no pressure on the annulus. The annulus was pressured up to 300 PSI but the pressure fell off rapidly to about 150 PSI in one minute. When SRU 31'33WD was completed in 1981, 7 in. Casing was set at 2450 ft. and was cemented to surface. A poor cement job was obtained and numerous holes were per.forated between 100 ft. and 430 ft. and squeezed with cement. The casing was perforated between 2100 ft. and 2383 ft. :Three and one-half inch fiberglass tubing was run and set in a packer 'at 2050'ft. The injected water is apparently all being disposed of thr°ugh the perforations below the packer since there was no pressure on the annulus. It appears that the perforations between 100 ft. and 430 ft..were not completely squeezed off and allowed the annulus pressure to fall off. Steps to repair 'the casing were not determined at this time. The second well to be tested was SRU 32-33WD. The three and one-half inch fiberglass tubing which was installed when this well was completed in 1981 had just been replaced with three'and one-half inch steel tubing. Water was not being injected due to the water lines being disconnected. The annulus was pressured up to 925 PSI which slowly fell-off to 920 PSI and then gradually' increased to 950 PSI after 35 minutes. While the pump and test equipment was being moved to the second well, we inspected the water disposal facilities and the other disposal wells. A workover rig was being rigged up on well SRU 243-4 to work over the well and run tubing and packer. In summary, I witnessed a successful mechanical integrity test on SRU 32-33WD and an unsuccessful test on SRU 31-33WD. ~GANNED f-\PP i ~ 2003 02.00lA,Rev. '0/79/ . TRANSMITT,\Ii ".ND ACKNO~q,EDGEMENT OF RECEIPT.ii · bb\TERIAL - (ALASKA) DATE THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. FD- Folded R - Rolled S - Sepia F - Film - Xerox B - Blueline PLEASE CHECK AND ADVISE IMMEDIATELY. C 31z.' -?, _L i ,-- ii~ i R£MARKS ON oTHER -- Ill[ I I Ill[ ii -- - I . - ~m-wo~~--~ :~.sa. ZNc. . BOX 7..839 SIDE , THIS SflE"E'T A~,.,Y'D4.. F')DAC'~E, A~SKA 99510 I I II II ~ I II~ ~ll I Ill I Illlm I , .% TYPE A2 I00' I01' 3:~0~ ,J.P. ,$?o' ~7 ~' t80' 381' 42'$' 426' 4?.9' 4~0' Z050' 21oo 2140 :~ I I 2,82 ~ . 22~6 * ·° 2264 2~1~' ~ ~ ~ 2~83' . _ ~ T.D. 2461' TUBLNG HANGER .312'' 4- ~'z" H/F (SOD) 3~' $.71"0.D. 3.02" I,D. 2000'~ WP STAR FIBERGLASS H.R THREADED EUE 8 Ro .. MODEL f-I BAKER PACKER W/SEAL ASSLY. ' (WIRE LINE MEASUREMENT) · WORKOVER 9- 8-81 7 SRU 31- 33 w:O. CASING & TUBING DETAIL SECTION 33 T. 8N., R. gw. SM CHEVRON U.S.A. INC. I I COMPLETION REPORT- REMEDIAL AREA: Swanson River Field Kenai Peninsula, Alaska PROPERTY: Swanson River Unit WELL NO: SRU 31-33 WD LOCATION AT SURFACE: LAND OFFICE: Anchorage LEASE NO: A-028399 APl NO: 50-133-20336 961' South and 1386' West from NE C~rner Section 33 T8N, R9W, ~{. LOCATION AT TOTAL DEPTH: ELEVATION: 165' GL DATE: San~ BY:~' T.L. AREA SUPERVISOR DATE COMMENCED REMEDIAL WORK:, DATE COMPLETED REMEDIAL WORK: RETURNED TO PRODUCTION: N/A July 5, 1981 September 4, 19.81 SUMMARY TOTAL DEPTH: 2461' EFFECTIVE DEPTH: 2406' ' CASING: 10 3/4" Conductor at 80' 7" Cemented at 2461' PLUGS: 3uly 5, 1981 Moved in with Gearhart Industries, Inc. differential temperature log. Wireline Service and prepared to run July 6, 1981 Gearhart ran a borehole audio tracer survey from 200' to 2408' and differential temperature log from 50' to 2408'. July 10, 1981 Rigged up Gearhart and ran a cement bond log with Gamma Ray/Neutron and Seismic Spectrum from 52' to 2408' with second run Cement Bond Log with Gamma Ray/Neutron from 52' to 2408' then moved off location. Shut well in. August 10, 1981 Rigged up Tolloff Construction crane contracted to R. L.'s Oilfield Service with tubing handling tools. Ran into hole with Baker 47B Model "C" retrievable bridge plug on 2 7/8" tubing. Set plug at 474' and pulled out of hole. Dumped nine sacks of sand down 7" casing. Landed on bridge plug at 474'. August 11, 1981 Made up Gearhart perforating tool with 4" H.S.C. using DML 23 charges, jet perforated 4 ½" holes from 424' to 425' and pulled out. Well began to flow fresh water from down hole. Rigged up and pumped 46 barrels of 11.1 ppg mud down hole. Unable to stop water flow. Pumped another 40 barrels of 12.1 ppg mud down hole and killed well. Gas coming out of the 7" x 10 3/4" annulus. Pulled out of hole and rigged up Baker 478 Model C full bore retrievamatic cementer on 2 7/8" tubing. Set packer at 332'. Mixed 75 .sacks of Class "G" cement with 3/4% D-31 and 15 gallons D-45L (B.J. Hughes) with pressure at 500 psi slowing to 200 psi. Displaced hole with four barrels of mud with pressure holding at 200 psi. Was unable to stop small gas leak. August 12, 1981 Waited on cement 12 hrs. Gas still leaking around surface pipe. Pulled packer out of hole. Made up 6" bit, dyna drill, and drill collars on 2 7/8" tubing. Ran into hole and tagged cement at 335'. Drilled stringers and hard cement to 425' circulating sand out from 425' to 470'. Pulled out of hole. Ran in hole with retrieving head and retrieved bridge plug at 474'. August 13, 1981 Gas still coming out of the 7" x 10 3/4" annulus. Ran in hole with open ended 2 7/8" tubing. Broke down perfs (424' to 425') using water at 1500 psi. Pumped ½ bbl. at 4 BPM and 600 psi. Rigged down. Flowed well back. Will flow back until pressure is zero. Moved crane to SRU 32-33. t~,~ ;:~{!~ ~!,~:~ ~i, August 21, 1981 Rigged crane back up on hole. Nippled up B. J. Hughes and killed well with 11.2 ppg mud. Pulled 15 joints of 2 7/8" tubing, picked up Baker Model C bridge plug, ran in hole and set at 474'. Pulled out of hole with tubing, spotted eight sacks of sand on bridge plug. R/U B. J. Hughes and squeezed perfs 425' - 426' with 50 SX of Class "G" with 2% CaC12, 3/4% D31, and 15 gal. R-45-L. Displaced with mud. No squeeze pressure seen. Shut well in. WOC. August 22, 1981 Shut in - WOC. August 23, 1981 Ran in hole with 6" bit, dyna drill, and drill collars on 2 7/8" tubing. Plugged bit with cement, pulled out of hole. Cleaned bit. Ran in hole with 6" bit, plugged bit again, pulled out of hole and cleaned bit. August 24, 1981 Ran in hole with 6" bit, dyna drill, and drill collars; drilled 6' of hard cement down to 426'. Pulled out of hole, rigged up Gearhart, and perforated 4 CJPF at 370'- 371' using 4" HSC with DML 23 charge. Rigged up Halliburton and cement squeezed perts 370'- 371' with 60 SXS of Class "G" with 2% CaC12, 0.5% Halad 4, and 0.5% CFR-2. Squeeze was successful. Shut in and waited on cement. August 25, 26, 1981 Gas no longer coming out of 7" x 10 3/4" annulus. Picked up 6" bit, dyna drill, and drill collars. Ran in hole on 2 7/8" tbg. and drilled out hard cement. Pulled out of hole and made casing scraper clean out run. Ran in and retrieved bridge plug. Rigged up Gearhart and perforated 4 CJPF using a 4" HSC gun the following intervals: 2383' - 2313', 2284' - 2256', .2242' - 2162', and 2140'- 2100' (884 holes). Gas started coming out between the 7" x 10 3/4" annulus and the 10 3/4" x conductor. Ran in and set 7" Baker bridge plug at 474'. Rigged up Gearhart and perforated 429' - 430' (4 holes) using a 4" HSC casing gun. August 27, 1981 Killed well with 10.6 ppg mud using Halliburton. Braden head squeezed perfs 429'- 430' with Halliburton using 43 SX of Class "G" with 0.5% Halad 4, 0.5% CFR-2, 2% CaC12 (1.15 cu. ft/sk yield, 15.8 ppg). No squeeze pressure seen, shut well in, and WOC. August 28, 1981 Picked up 6" bit, dyna drill and drill collars. Ran in hole and drilled out cement. Pressure tested squeeze, squeeze would 'not hold. Ran in hole open ended. Rigged up Halliburton and squeezed perfs 429' - 430' using 43 SXS of Class "G" with 0.5% Halad 4, 0.5% CFR-2, and 2% CaC12 (1.15 ft3/SX yield, 15.8 ppg). No squeeze pressure seen, over displaced perfs, and resqueezed using 43 SX of same cement. No squeeze, over displaced cement. 'i.~ iii! ~'~' ?ii~' August 29, 1981 Resqueezed perfs 429'- 430' with Halliburton using 75 SX of Class "G" with 0.5% Halad 4, 0.5% CFR-2, and 2% CaC12 (1.15 ft3/SX yield 15.8 ppg). Staged cement into perfs for a 150 psi pressure increase. Shut well in and WOC. ..August 30, 1981 W.O.C. August 31, 1981 Gas still coming out of annulus. POOH wi.th 2 7/8" tubing. RIH with 6" bit, dyna drill and drill collars and drilled out hard cement. Rigged up Gearhart and perforated 380'- 381' (4 holes) with 4" casing gun. RIH with open ended 2 7/8" tubing. Rigged up Halliburton and squeezed perfs 380' - 381' with 50 SX of Class "G" cement with 0.5% Halad 4, 0.5% CFR-2, and 2% CaC12. No squeeze, overdisplaced hole. September 1, 1981 R/U Halliburton and squeezed perfs 380' - 381' using 119 SX of Class "G" cement with 0.5% Halad 4, 0.5% CFR-2, and 2% CaC12. Staged in cement. WOC. September 2, 1981 Pulled tubing. RIH with 6" bit, dyna drill, and drill collars, and drilled out cement to 373'. Gas still coming out the annulus. Broke down perfs 370' - 371' with 1100 psi. Rigged up Halliburton and squeezed with 80 SX of Class "G" cement with 0.5% Halad 4, 0.5% CFR-2, and 2% CaC12. (1.15 ft3/SX, 15.8 ppg) to 350 psi final pressure. Shut in - WOC. September 3, 1981 Gas still coming out annulus. RIH with 6" bit, dynadrill, and drill collars. Drilled out cement to 325'. R/U Gearhart and perfd 320'- 321' (4 holes). R/U Halliburton and squeezed perfs 320' - 321' with 43 SX of Class "G" cement with 0.5% Halad 4, 0.5% CFR-2, and 2% CaC12 to 250 psi. Over displaced perfs, resqueezed with 50 SX of same cement to a final pressure of 400 psi. September 4, 1981 Gas still coming out of annulus. Drilled out cement to 300'. R/U Gearhart and perforated 100'- 101' (4 holes). R/U Halliburton and squeezed perfs 100' - 101' with 108 SX of Class "G" cement with 0.5% Halad 4, 0.5% CFR-2, and 2% CaC12. Had cement returns to surface out of the 7" x 10 3/4" annulus. September 5, 1981 Shut down. DIRECTIONAL SURVEY WELL #SRU 31-33 W.D. Depth 2450' -}o 5/23/81 September 6, ?, 8, 1981 No gas coming out of the 7" x 10 3/4" annulus or the 10 3/4" x conductor. Drilled out cement plug down to the bridge plug at 474'. Pressure tested casing to 300 psi for 15 minutes - held o.k. Pulled bridge plug. Made 7" casing scraper run to 2383'. Set Baker 7" Model FI retainer production packer (413-06-8540) at 2050' with Gearhart. Ran 3~" (3.71" OD, 3.02" ID), 2000# W.P. Star Fiberglass HP EUE 8rd tubing with Baker packer anchor. Latched into packer at 2050' and landed tubing in 6000 lbs. tension (16" stretch tensile strength 20,000 lbs.). Nippled up tree and turned well over to the production foreman. NELL NO.. ~',q::)(.J I,.,~]' ,..~'/-,.5',~ COUNTY OF SECTION NO._ ~ . , TO~YNSHIP o° tk] ~ELL SURVEY Pro-312 /~'"~/-/o / CITY OF u, eE. ? ,,,,./' r-n s.B. jt. ~ ,. TRACT NO. LOT NO. FI ELD ELEVATION: GROUND CONCRETE HAT DERRICK FLOOR ALTERNATE OR SURVEYED LOCATION LOCAT I ON DES I ~JIATI ON LOCATION COORD I NATES HOVE RE;HARKS ! ,Z-'~n~/ /~ 22 I~<..~ /',v,',4/ ~- 2 .~"* *"'.'" '" :. i '.- ;, ., -[ NORTH SKETCH OR REHARK$ , i , "'~i ' ' ' .~:~''',- ~ ~ .~ · __~ '. ~ , ~ .,, . . ~,__.~.',.~. ~ ~.~ ~.'~ ..... . s ] ~ff~1~ ..... .,-. -...- - .. . :~ , . -~~~ : ~' .': ~: ;',": , B~ HARK IS: ~or¢~ r/,~, ~A' ,.x- /" ' "' . STATION BEARING DISTANCE SINE COSINE NORTH SOUTH: · '"EAST VEST" .. , · · .,. '.' _ ~" , 'i;, ~' ~ ' ... .~ .... DIY, SURV~OR,'~; ~,~',~HAINT. F~. ~INT. ~PT. ,' rILE DATE /~ ~/~,'~ /~/' DATE ~TE LOGS: Schlumberger: JDual Induction Log j,'Formation Density Log ,/Compensated Neutron · GO GEARHART '/Borehole Audio Tracer Survey ~.,/Differential Temperature Log Cement. Bond with Gamma Ray/ Neu. t.ron ,/CBL with GR/Neutron-Seismic Spectrum 90'-2527' 90'-2529~ 90'-2529' 200' -2408 50'-2408 52'-2408 , 52'-2408 5-23-81 5-23-81 5-23-8i .- 7-6-81 7-6-81 7-10-81 7-10-81 COMPLETION REPORT - NEN ~11 AREA: Swanson River Field Kenai Peninsula, Alaska LAND OFF I CE: Ancho rage PROPERTY: Swanson River Unit LEASE NO: A-028399 WELL NO: SRU 31-33 WD AP! NO: 50-133-20336 LOCATION AT SURFACE: 961' South & 1386' West from NE Corner Section 33 T.8N., R. 9W. SM LOCATION AT TOTAL DEPTH: Same ! ELEVATION: 165' GL DATE: T. L, Perryman AREA SUPERV! SOR ,.i DRILLED BY: "' Brinkerhoff Rig #60'Contractor DATE COMMENCED ~I~I~;~_XWORK: May 17' 1981 DATE COMPLETED ~ I~ORK: May 24, 1981 RETURNED TO PRODUCTI ON: TOTAL DEPTH: 2461' EFFECTIVE DEPTH:2450 CASING: 10 3/4" Conductor @ 80' 7" Cemented at 2461' SLM~RY PLUGS: M'ay 17, 1981 Completed location and drove 10 3/4" conductor to 80'. May 18, 19, 1981 Moved Brinkerhoff Rig #60 onto location and completed rigging up at 4'00 PM. May 20, 1981 Installed 10" - 2000# diverter. Mix mud and commenced drilling at 10:30 PM drilling to 200' Mud 71.9 pc~ May 21, 22, 1981 Drilled from 200' to 2360' with 9 7/8" bit. Mud 71.9 pc~ May 23, 198~ Drilled from 2360' to 2450' Pulled out of hole and repaired rig fast coupling. Ran into hole with 9 7/8" bit to 2450'~ :circulated for two hours, pulled out of hole. 'Rigged up and Schlumberger Dual Induction Log from 90' to 2430', ran compensated formation Density.Log from 90' to 2440'. Ran compensated Neutron-Formation Density from 90' to 2440'. Completing log runs. Ran into hole with 9 7/8" bit drilled to 2461'.Circulated for two hours, started out of hOle. Mud 74.9 p¢~ May 24, 1981 Completed, pull out laying down 7" drill collars. Rigged up and ran into hole with 57 joints of 7" 29th 8rd. casing landing at 2461' with 'float collar at 2410'. Circulated and cemented 7" casing with 800 sks Class "G" cement with 2% calcium chloride, cement in place with good returns to surface, time elapsed three and one half. hours. Cut 7" and nippled up hydril. Ran into hole with 6" bit found top cement at 2406', circulated. Rigged up laid down drill pipe and removed B.O.P. Clean mud tanks and released rig at 10:00 AM. JWW:sjb J. W. WILSON Chevron Chevron U.S.A. Inc. P. O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 ~ 0 ~-C C. Scut ,,/[R-q. RECEIVED ,jUN 3 Alaska Oil & G~s Cons. Commission Anchorage February 4, 1983 Mr. T. L. Per ryman Area Operations Superintendent Chevron U.S.A., Inc. P. O. Box 7-839 Anchorage, Alaska 99410 Dear Hr. Perryman:' The Alaska Oil and Gas Conservation Commission. has recently checked the records of ~ells completed since January 1, 1979. This review has revealed that the digitized data for certain logs run in a well is not on file with the Commission. The Oil and Cas Regulations require the operator to file, '~.~itb. in' 30 days after completion, suspension., or abandonment of a drilling v~ell, the digitized data, awaiiable, for copying, for all logs run in' the well except velocity s'urveys, experimental logs and. ait~- ~eter surveys ~4e would request that yo%~ check your records to see if the data has been su'bmitted to the ' ~ Commzssion and, if not, that you comply with the regulation with regard tc the we! ls: Swanson ~ ' , ,~,~o 31-33 WD R~ver Unit "' . Sol dotna ,: . Creese Unit No 44-8A Pretty Creek, Unit No. 2. .$o!d.otna Creek Unit .No. ].2-3A ,,~oldotna Creek Unit !':~o. 41-9A .Thank you for your cooperation in. this matter. Yours very truly, ,~* WELL SURVEY Pro-312 .'IIELL NO.~..~'~ I,,q']'_ ,~/-~ COUNTY OF...~/"/0 ,' '" SECTION #0._ ;,.T-'J' .' .. TO'I'N$#IP o°/u~ I~eE 2 ~/ .,, · -' 'TINCT NO.j IZ3 PROPOSED - [] PRELIMINARY ~i~ FI NAL CITY OF s.a,L & )4. ELEVATION: GROUND CONCRETE HAT DERRICK FLOOR "' A LT E RN AT E OR SURVEYED LOC A T I ON LOCATI'ON ' ' .'. , DESIGNATION LOCATION COORDINATES ' #OVE RE:HARKS '. , , ,~na/ i~ 2£ /00 /91.41 E 2 02~~.,~..%,~~.~" · " '. ....... '", < . . · ::'. *, . , '. ', ,,.:. .. .,:':. · .... ! !'::' ...~,i,i~..~ .... . .,t.;x, .~.:.:, ' . · -. .. , .: .. '.., ~ .:. :,',;,,...."',' , · .. ., ,. ~, -' , .~. '. . ., . · , . ,< , .:....',." .%,.:~..' . , .. . . -'... · . · · . . · : , ... . ' ., "' ,~..L ' ' '" · .... · ,,, ' ' ' ' ..... '" '"'.':',',':i ..... . . . . .', . . i , . -.. ' .,~ ... ~ : ~ , , · , {' .,". ..,.. :, · , , , ~ . . . , . . ':,. ... . . ~. . ., . ~:., . .'. ' ' ',',: ...... " ' ' .' " .:.':',:.i. ' ': .... ";~ ,,, ' . .~,. -t. I I 1 ! I I I NORTH · ,.i~l .- . I SOUTH BE~CH HARK IS: ~/~ SKETCH OR REHARKS .':~?i'~,"~ '. ~'d'~, ' ' .. ..... . · · . o · . . ~'? ~.' . · ,,, ,_ · .:.~:- · :,, * .... c. . ,..,,..' . .. · , ,',.. , , .~ . . . ..... :. ~, '/~= , :. ,~ .-" : ' ,r . , STATION BEARING DISTANCE 'SINE "C08111E ,. '.NORTH SOUTH' ,::.-'EAST . VEST' L . '!:. ,:'..,, ............. '..,'. .... .., ~.,. .,:~:,~.:.:,:'~..~:.}:. .~?,":' ."..':-i ,, -;, [ . , - . , I~ , . ' :, ' :,,,";:~';~" ?-c.., .'t~ ~,,,,.. .,' ':, .... . -.{':.':., '"": :.'?q..... .... :, '";:' , . ~ . . · . ~ : , ; ..~., ~.. - .... ' ' ' '- ~' "'.:."Z:;~: · . ,,. ~,~,~L,.:~~ . '- ,'/' ~ '. .~-', . . . , ' . .. . .:.:..:,.:.. ~, , ,~ . · ...... . ..~:.~._::. '.,.. ,.. .,.'., · ,'. , ::..,..';:"' :'!':i:~.":'.'-', · , . '.~ ,. C.C. DIV. ENGR. FI LE PIll?lo II .~ . . ,>.... ':.'.,~.~ :., ,:. -.., ":'.:v ,~.~, ,'.. {4:: .: ':.:~.', "'%' '::~-,,,~ S~V~O~.r~:., ~.,~ ~I~T, F~, " ~l~T, ~T. "' ..... ~,,..:s.,.~ . _ ~TE t~ ~ma IgSl ~TE '~ ">: :q'::::'.:: - '"" Chevron TRANSMITTAL ~? CHEVRON' U.S.A. INC. .~ ACKNOWLEDGEMENT OF RECEIPT 01 ATERIAL - (ALASKA) TO: DEPT.: DATE PLACE: ., THE FOLLOWING IS A LIST OF MATER. IAL ENCLOSED HEREIN. FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline PLEASE CHECK AND ADVISE IMMEDIATELY. RECEIVED BY REMARKS ON OTHER SIDE, THIS SHE'ET ~ 7-839 ANOtORAGE~ ALASKA 99510 !Ui( Y-ra~ s r~; H~I Z)A--F£ % ~ p/,,N. Bcue 0/~¢--. -81 ,.-- :5- 2.2-8~ :-- a. c/::moW lc d~ omen4 Cherry% U.S.A. Inc. P. O. Box 7-839 An~ge, Ala~ 99510 A~_~ril 21, 1982 Beluga River Unit $214-35 (2nd notice; see attached of 10/8/Sl Soldotna Ct. Unit %21-4A -Well History -Sm~les & Core Chips Gore Des iptiun ~ied Survey Plat -D~cnal Survey -Digitized E. Log Tape q,~ell History -Certified Survey Plat -Digitized E. Log T~pe Soldotna Ct. Unit ~42-5A lO/S/81 ~/1 History -Elec. Logs -Digiti?~d E. Log Tape Soldotna Cr. unit #44-8A 11/7/81 ~ell ~{isto~f Soldotr~% Cr. Unit 941-9A Swanson Ri~_r 5Y~t #31-3~D River Unit ~32-339~ 6/2/81 , 5 9/8 4~ell History -Elec. L~js -Digitized E. Log Tarn -I/acl//%atio~ Survey -Digitized E. Log Tape -well -Certifi~ SuTvey Plat -~linati~n Sur~%, -Digitize~ E. Log Tape Please suhnit the above material at your earliest ccn~enoe since you are. nc~ in violation of Title 20, Chapter 25 of the Alaska ~trative Code. Very truly yours, BY' oND~.R O,= THS CO~{NIIS$10N CO~fPT~NY WELL RUNS / TtG\NSHITTAL AND ACKNO~EDGEbUZNT OF RECEIPT OF HATERI~kL - (ALASKa\) DEPT.: ~ (~ ~ · . THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. CHECK AND ADVISE IHb~DIATELY. ..SRO .31, SS. WE:) . INDUCTION ELECTRICAL LOG DUAL INDUCTION L~.~DG - SFaC BOREIIOLE COMPENSATED SONIC BOREHOLE COMP. SONIC w/caliPer BOKEIIOLE CO~P. SONIC w/gamma BOREItOLE TELEVIE~q~R CONTINUOUS DIP,',~TER- High Res. CDH- POLlq~OG PLOT CEmeNT BOND LOG CASING COLLAR LOG - Perf. Rec. CObfPENSATED FORI. LATION DEN. CObfPENSATED NEUTRON ANALYSIS LOG DENSITY LOG F F TESTER FACTOR F F FO~DITION FOR~XL&T ION FOR>LATION FOF&bkTION 6A/,D.IA RAY G~t~ ~Y G~ I~Y MICRO LOG - NEUTRON COLLAR LOG MI CROLATEROLOG MUD LOG NEUTRON LOG PROXIHITY MICROLOG RWA CO,~[PARISON PLOT SANDSTONE ANALYS IS SARAJ3AND SIDEWALL NEUTRON POROSITY SONIC TE~tP ERATU RE LOG CO~<PLET IO,q REPORT D I ?OJCT I O,'~AL SURVEY CORE DATA SAF~\BA_ND TABULAR LISTING ~" 5N PLEASE SEPIA ./ ! · BLUELINE / Alaska Oil & Gas.Cons. Oommission Anchorage I I IOO 200 . STATE OF ALASKA 0 I1~ I 6 I ~ ALASKA( AND GAS CONSERVATION C¢ ON WELL COMPLETIUN OR RECOMPLETION RE, PORT AND LOG 1. Status of Well Water Disposal Classification of Service Well Confidential OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICEx[~] _. 2. Name of Operator 7. Permit Number Chevron USA Inc. 80-114 3. Address 8. APl Number P.O. Box 7-839 Anchorage, AK 99510 5o- 1~3-20336 4. Location of well at surface 950' S + 1450' W of NE corner of Sec.33, T8N, 9. unit or Lease Name R9W, SB+M. Swanson River Unit At Top Producing Interval Same 10, Well Number SRV 31-33WD At Total Depth Same 11. Field and Pool Swanson River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 163' GL A-028399 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. or Aband. ] 15. Water Depth, if offshore' 116'No'°fCompleti°ns 5-20-81 5-24-81 5-24-81[ feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafros't 2461' 2406' YES [] NO ~[]] feet MD None 22. Type Electric or Other Logs Run Dual Induction, Densilo§, Compensated Neutron Gamma Ray 23, CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT, PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 10' 3/4"' Conduct ~r Surface 90' Driven 77" 29# K-55 Surface 2461' 9 7/8" 800 SX Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval,, Size and number) :" SIZE DEPTH SET (MD) PACKER SE~- (MD) ' None 'NONE 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. . DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED NONE ,, , 27. PRODUCTION TEST I Date First Production .. Method of Opera. tion (Flowing, gas lift, etc.) , NONE Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs:McF WATER-BBL ~HOKESIZE IGAS-OIL RATIO ! . . TEST PERIOD.~ I Flow Tqbing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press .... 24-HOUR RATE 28. CORE DATA · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32.' I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~~." '~/" ~:,/~,;z'~'Y'~"r~ff"~'"(,~'''/¢~1//' ' '~ ~" Title Area 0per. S~p.t, Date _h-z -BI INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: I'f this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA .///,/: ' ALASK " 'L AND GAS CONSERVATION C¢i~ :MISSION MONTHLY REPOR DRILLING AND WOR OVER OPERATIONS Natne of operator :', 7. Permit No. Chevron USA Inc. 80-114 3. Address 8. APl Number P.O. Box 7-'839 Anchorage, AK 99510 5o- 133-20336 4. Location of Well 950'S + 1450'W of NE corner of Sec. 33, T8N, R9W, at surface SB+M. 5. Elevation~i.,'~- ~,~c;icate~B,.163 GDIF'etc')I 6. Lease Design~t]~n2~(~rial No. ~l'.~._~it or Lease Name Swanson River Unil: 10. Well No. SRU 31-33UD 11. Field and Pool Swanson River Field For the Month of May ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded 5-20-81 DRLD. to 2461' Rig released 5-24-81 13. Casing or liner run and quantities of cement, results of pressure tests 10 3/4" Conductor driven to 90' 7':' Casing cemented to 2461' w/800SX Class "G" 14. Coring resume and brief description 15. Logs run and depth where run Dual Inductiog Compensation Densilog, Compensated Neutron Gamma Ray to 2450' 16. DST data, perforating data, shows of H2S, miscellaneous data ECEIYED' JUN - 8 1981 At~ska 0it & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Repo~t.o~.thi~,,~l~uired for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 Check Form for timely compliance with our regulations. Operator, Well Name and Number Reports and Materials to be received by: Completion Report Wel 1 H~s.t_o__ry Samples Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey Required i Date Received Yes } ~__~;:~_ (~;~ / Yes Date Remarks Directional Survey Drill Stem Test Reports Production Test Reports . ..... ~lo~e~ ~ .... 0 t/',, , , Logs Run Yes ~~~.~..~_~ ~ ~a!,,~,:~.X ....... h~ ....... (907) 465-2600 Mr. R. W. Magee Area Engineer Chevron, U.S.A., Inc. P.O. Box 7-839 Anchorage, Alaska 99510 Dear Mr. Magee- POUCH 0 - JUNEAU .~I1 / CERTIFIED MAIL RETURN RECEIPT REQUESTED March 9, 1981 The Department of Environmental Conservation has completed its evaluation of your two Waste Disposal Permit applications~ for dis. posal by underground injection of liquid wastes resulting from oil and gas production activities and is issuing the enclosed permits 8120-DBO01 and 8120-DB002 in accordance with AS 46.03.100-110 and 18 AAC 70..Please review the conditions and stipulations in each permit and insure they are all understood. If you disagree with any portion of these permits, you may request an adjudicatory hearing by filing a statement of issues under AS 44.62.370 within thirty (30) days of receipt of this letter. The statement of issues should be mailed to the Alaska Department of Environmental Conservation, Pouch O, Juneau, Alaska 99811, or delivered to our office at 3220 Hospital Drive, Juneau. The filing of a statement of issues entit.les you to an adjudicatory hearing to contest the permit. Failure to file a statement of issues within thirty (30) days of receipt of this letter shall constitute a waiver of your right to judicial review of these permits. Enclosure Sincerely, C~.' /'~~'~Deml'ng ~o~ Deputy Commissioner RECEIVED cc' ~ EPA, Alaska Operations Office [0. K. Gi lbreth._,__D.i_v__is_i_o~L.o£__Oil_and Gas Conservation MAR 1 1 I98! ........ Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA DEPARTMENT OF ENVIRONMENTAL CONSERVATION POUCH 0 JUNEAU, ALASKA 99811 WASYE DISPOSAL PERMIT No. 8120-DB001 Date' This waste disposal permit is issued to Chevron, U.S.A., Inc., P.O. Box 7-839, Anchorage, Alaska 99510, for the disposal of liquid industrial waste resulting from oil and gas production. The liquid industrial waste will be disposed of into the ground through Well SRU 31-33 WD located at the Swanson River Oi,1 Field (Section 33, T8N, R9W, S.M.). This permit is issued under provisions of Alaska Statutes AS 46.02.100-110, Water, Air and Environmental Conservation, the Alaska Administrative Code as amended or revised, and other applicable State laws and regula- tions. ,, This permit is effective upon issuance and expires January 1, 1986. It may be terminated or modified in accordance with AS 46.03.120. C. Demi ng CoWes Deputy Commissioner RECEIVEI) Anehor~e Permit No. 8120-DB001 ~ge 2 of 4 A. LIMITATIONS 1. During the period beginning on the effective date and lasting through the expiration or termination date, the permittee is authorized to dispose of liquid industrial waste by underground injection. 2. The discharge of liquid industrial waste and/or a flow of water onto the surface of the ground as a result of this underground injection is prohibited. 3. The liquid industrial waste may not be disposed of at a depth of less than 2,100 feet beneath the surface of the ground. 4. The quantity of liquid industrial waste disposed of shall not exceed 420,000 gallons per day. 5. The liquid industrial waste disposed of shall only consist of produced water from oil and gas production. B. MANAGEMENT REQUIREMENTS 1. Change in Liquid Industrial Waste Disposed of The disposal of liquid industrial wastes authorized herein shall be consistent with the terms and conditions of this permit. The disposal of any pollutant identified in this permit, or toxic material, including oil, grease or sol vents, more frequently than or at a concentration or a limit not authorized shall constitute noncompliance with this permit. Any anticipated facility expansion, production increase, process modification, or change in any chemicals used which will result in a new different, or increased amount of pollutant being disposed of must be reported by submission of a new Waste Disposal Permit application. If such change will not affect the ability of the permittee to comply with the limitations specified in Section A of this permit, the permittee shall submit written notice to the Department sixty (60) days prior to the commencement of such changes. 2. Toxic Pollutants If a toxic pollutant, including oil, grease or solvents, concen- tration standard is established in accordance with 18 AAC 70 for a pollutant present in this discharge, and such standard is more stringent than the limitation in this permit, this permit may be modified in accordance with the toxic pollutant concentration standard. Permit No. 8120-DB001 Page 3 of 4 3. Noncompliance Notification a. If for any reason the permittee does not comply with or will be unable to comply with any effluent limitation specified in this permit, the permitee shall report the noncompliance to the Southcentral Regional Office of the Department, 435 "E" Street, 2nd Floor, Anchorage, Alaska, 99501 (274-2533) within 24 hours of becoming aware of such condition by telephone, telegraph, or in the absence of both, by mail. b. A written follow-up report shall be sent to the Department within seven days of the noncompliance event. The written report shall contain but not be limited to' (1) times and dates on which the event occurred and, if not corrected, the anticipated time the noncompliance is expected to continue. (2) a detailed description of the event, including quantities and types of materials involved. (3) details of any damage to the receiving environment. (4) details of actions taken or to be taken to correct the causes of the event. (5) details of actions taken or to be taken to correct any damages resulting from the event. 4. Adverse Impact The permittee shall take all necessary means to minimize any adverse impact to the receiving environment resulting from noncompliance with any limitations specified in this permit, including such monitoring as necessary to determine the nature and impact of the noncomplying discharge. The Department may require the permittee to undertake cleanup activities in the event of an adverse impact resulting from noncompliance. C. GENERAL 1. Right of Entry The permittee shall allow the Commissioner of Environmental Conservation or his authorized representative, upon presentation of credentials' a® To enter upon the permittee's premises where either the waste collection equipment or the discharge well are located at such times and upon such terms as the Department may reasonably require; and bo At reasonable times, to have access to and to be allowed to copy any records .required to be kept under the terms and conditions of this permit and to inspect any monitoring equipment or monitoring method required in this permit. Permit No. 8120-DBO01 ge 4 of q 2. Transfer of Ownership or Control In the event of any change in control or ownership of facilities from which the authorized discharge emanates, the permittee shall notify the succeeding owner or controller of the e~is~ence of this permit by letter, a copy of which shall be fc. rwarded to the Commissioner of Environmental Conservation. 3. Availability Of Records Except for information relating to secret processes or methods of manufacture, all records and reports prepared and submitted in accordance with the terms of this permit shall be available for public inspection at the offices of the Alaska Department of Environmental Conservation. 4. Property Rights The issuance of this permit does not convey any property rights in either real or personal property, or any other privileges; nor does it authorize any injury to private property or an invasion of personal rights, nor any infringements of Federal, State or local laws and regulations. 5. Severability The provisions of this permit are severable, and if any provisions of this permit or the application of any provision of this permit or the application of any provision of this permit to any circumstances is held invalid, the application of such provision to other circumstances and the remainder of this permit shall not be affected thereby. Notwithstanding the above, in the event that such invalidation materially alters the scope or conditions of this permit, the Department shall have the right, at its sole option, to terminate the permit. 6. State Laws Nothing in this permit shall be construed to preclude the institu'cion of any legal action or relieve the permittee from any responsibilities, liabilities, or penalities established pursuant to any applicable State laws or regulations. 7. Posting of Permit The permittee shall post a copy of this permit conspicuously at the disposal site and maintain a copy of it in their files. November 12, 1980 Mr. R. W. Magee Area Engineer Chevron U.S.A., Inc. P.O. Box 7-839 Anchorage, Alaska 99510 Subject: Swanson River Unit SRU 31-33 WD Swanson River Unit SRU 32-33 WD Dear Mr. Ma§ee: The API numbers assigned to the 16sted wells on the permit to drill forms were erroneous and need to be corrected, SRU 31-33 WD is assigned API number 50-133-20336, SRU 32-33 WD is assigned API number 50-133-20337. We apologize for any inconvenience this may have caused. Sincerely yours, :_.../:..____. ,, /:. John A. Levorsen Petroleum Geologist JAL/ge October 8, 1980 Mr. R. W. Magee Area Engineer Chevron U.S.A. Inc. P. O. Box 7-839 Anchorage, Alaska 99510 Re: Swanson River Unit SRU 31-33WD Chevron U.S.A. Inc. Permit No. 80-114 Sur. Loc.= 950'S, 1450'W of NE. cr Sec. 33, TSN, R9W, SBM. Bottomhole Loc.: S A M E Dear Mr. Magee: Enclosed is the approved application for permit to. drill the above referenced well. This permit to drill and complete does. not constitute approval for disposal of fluids, such permit must be obtained from the Alaska Department of Environmental Conservation. ., Well samples and a mud log are not required. A directional survey is not required. If available, a tape containing the digitized log information shall be submitted on all logs for' 'copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. R. W. Magee -2- Swanson River Unit SRU 31-33 WD October 8, 1980 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very 0~~ vo~rs, Hoyle H. Hamilton Chairman of BY ORD~ OF Alaska Oil & Gas Conservation Commission Enclosure cc: Department of Fish & Game, ~abitat Section w/o encl. Department of Environmental Conservation W/o/encl. Department of Labor; Supervisor, Labor Law Compliance Division w/o encl. HHH:be .(~"" STATE OF ALASKA ALASKA ,,_ AND GAS CONSERVATION CO¢: .,IISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work. DRILL E~ lb. Type of well EXPLORATORY [] SERVICE {~] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator CHEVRON U.S.A. INC. 3. Address P. O. Box 7-839 Anchorage, Alaska 99510 4. Locat~on of wel~ at surface 950' south and 1450' west of NE corner of 9. Un,tor~easename Sec. 33, T8N, R9W, SB&M Swanson River Unit At top of proposed producing interval 10. Well number same SRU 31-33 WD At total depth same 11. Field and pool Swanson River Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. ,, 163' GL ' A-028399 12. Bond information (see';20 AAC 25.025) Type nationwi de Surety and/or number SL-6205862 Amount $150,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 16.5 miles N. of Ken~Iles 2_5_00 feet we~ SRU-4]-33WD 30 .feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 2450 feet 1120 10/80 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures0 -psig@___--Surface KICK OFF POINT NA feet. MAXIMUM HOLE ANGLE oI (see 20 AAC 25.035 (c) (2) 1030 psig@ 2450 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 10 3/4 CONDUC--OR I 0 I 80 Driven 7" 23# K-bb Lf&C 2450 I 0 12450 2450' I I ' I I I I I I 22. Describe proposed program: _ I We propose to drill SRU 31-33 WD for the purpose of waste water disposal per the attached program. 23. I hereby certify tha~.t, the foregoing is true and correct to the best of my knowledge S,GNED ~.-~_ ... ~ ....... ~.."~/"¢::~....-~---'E~_...~ T,TLE Area Engineer DATE /~-~ The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required APl number . []YES (~JO []YES [~¢N.O I--lYES [~O 50-//,~ ~ "¢~-c~ ~'l~(~ Permit number Approval date ¢~'//~ 10/08/80 SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY COMMISSIONER DATE O(-:~tOt'~T' 8. 1980 .__ by order of the Commission Form 10401 Submit in triplicate Rev. 7-1-80 le 2. 3. 4. Be e (: PROGRAM Drive 10 3/4" conductor to + 80'. Install 10", 2000 psi diverter. Drill 9 7/8" hole to 2450'. Condition mud for logs. Run Dual-Induction Focused log and Compensated Densilog-Compensated Neutron-Gamma Ray log from 2450' to shoe of surface casing. a. Obtain 1/2 gallon sample of drilling fluid prior to pulling out for log. b. Use 10 MV SP, 0-50 ohm-meters scale on linear DIFL, 0-60% porosity scale, and 0-100 API units on GR. Run and cement 7", 23#~ K-55, LT&C casing at 2450' as follows: a. Use float shoe and float collar, float collar to be one joint above shoe. b. Install centralizers 10' above shoe, on top of shoe joint, and on every other joint for first 10 joints. c. Cement in single stage with sufficient Class "G" cement with 2% calcium chloride to obtain returns to surface. (Estimate 800 cu. ft. required including 20% excess.) d. Displace with lease water. WOC 4 hours. Land casing and install tubing head. RIH, locate top of cement. Perforate casing and run packer and fiberglass injection string per supplementary program to be issued by Area Engineer. FIGURE II1-1 DIVERTER-PREVENTER HOOKUP J FLOW LINE FILL-UP J LINE J TO MUD-GAS SEPARATOR ~ J . ~ ~ I:,- 1 ~ .~..ULAR DIVERTER ~ff~ DRILLING SPOOL VALVE VALVE DRIVE PIPE OR CONDUCTOR CASING NOTE: ALL LINES AND VALVES SHALL MEET ALL. REGULATIONS THAT APPLY. (SEE PAGE II1-1, A.I.a) ) EXTEND LINES IN DIFFERENT 'DIRECTIONS TO ENSURE DOWNWIND DIVERSION VALVE CHE!¥HCAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. P.O. BOX 4-1276 Anchorage, Alaska 99509 TELEPHONE (907)-279-4014 274-3364 ANCHORAGE INDUSTRIAL CENTER 5633 B Street WATER ANALYSIS REPORT DAT~ June 26, 1980 LAB LOCATION, FOR.~IATION INT~:RVAT- , 8ASiPL]Z FRO~ Produoed Water 4073-2 Sample taken June 16r 1980 Salinity as NaC1 (ppm) ,20109 5525 240.34 95 2.43 2470 123.25 40 3.29 12200 0 Bic~r~t~ 1535 '0.10 344.04 25.17 369.31 21098 20663 5.9 ~1 100 Na -- HCO~ 10 Ca -- SO, 10 ~g CO: 10 Fe O. 33 O. 33 ' ;- ~ I il 1l111 f ( i il i ( ;li. 7%1 i! ~ (t I !;fL {II :I1 4];!(ii¢111 /:II~ ~; II Il/fl ff!illtl (][II lltl~ ~llllflil(!i'l:illllf'frlflllllllillll[lf[ii[~ {liililf!llll.l;l!flfllllirlll[Iflii!{lllI:llil} ,~i' I-Ir!il ~2 {ii(, 121-l(~ ! I Iii 71 ;I1 ,7[ [II I [ ~ ii l:' Il- ' tlLL~I iii? [iililI{; ri :!!il i~ /lll[li I t Y.fl i [7 Il lil~l. flll i ~ [[_ ? [::; III ~7i ~ii lTf;~iflii:illkllill;li-r~lillfltfilfilYlfrllil FIG 8. WELt NO. SRLJ, 22 I -33 OIL B/D COMPANY $ [AHUARD Ti I L LOCATION A L 3. 5 K A SAMPLE SOURCE ZONE CO WATER B/D 109 GAS MCF/D 1536 OIL GRAVITY METHOD R~ 'PLE DATE c JRT DATE LABORATORY SAMPLED BY ANALYST 854 RADICALS PARTS PER MILLION MILLIGRAM5 PER LITER 1293.4 98.2. ·76.9 2.7 ~866.3 . Oe 902.4 4239.9 Oo · · E,'~UIVAL~-N'T SALT = .215.O CHLQ~INII'Y : /79,72 G/G~ hYDRU<;EN SULFIDE ABSENT GIG, RESISTIVITY SPECIFIC' GRAVITY REACTING VALUE PF.R MILLIO~I 56.26 4.90 6.33 0.0/:, 52.64 O. 14.79 134.97 .- =.l'.450 OHM-HE?ER =1.0045, PH = 7.91 REACTING VALL]E ~'~C£~T- 41 ·3 '4.69 0.04 39.00 Oe ' 10.96. 100.00 AT 77 DEG F STAB1L'ITY AT 1.00' F,. 4-420 SIGNED STANDARD OIL CO, of CALIE, W.O.I.,Opmr Swanson River Unit 221-33' Elev. 205' K.B Fr. hI.W, Car. Sec. 33 T, BN.,R.gW.,S. BB~M, · 560'5,8 2110'E, Surface Location Cl + I + Br 504 SRU 41-33 WI CONTOUR HORIZON ' ! · X' ---.-i ....................................... : ....... ................ : ........ ................... ~; ~ . PROP. ,! ~ ,I '~' '"'"'"x' /7 I 3~w~ /1~' / /'~ , ~~ ,// ./. . ~ ~ ~ ~/ /,.,'.o~: ,~ 2'4 ~ " . /' ~STRUCTURE MAP '"'"' i' ~ ..-" ~ .lco~ou.s o~ ~-.o~ MX~. 't- ~-""' ~ iUPPER {TERLI~ Fro. C}~CK LIST FOR NEW ?~LL PE~ITS Item Approve Date ( 1 ) Fee (]~ /o -~- ~ ~ (2) Loc. (3) /~Lmin. Company Yes No 1. Is the permit fee attached ......................................... 2. Is well to be located in a defined pool ............................. · 3. Is a registered survey plat attached ................................ Lease & Well No. Remarks. 4. Is well located proper distance frcm property line .................. ~' 5. Is well located proper distance frcm other wells .................... 6. Is sufficient undedicated acreage available in this pool ............. 7. Is well to be deviated .............................................. 8. Is operator the only affected party ................................. ~ / 9. Can permit be approved before ten-day wait .......................... ,~/~ 10. Does operator have a bond in force .................................. ~ 11. Is a conservation order needed ...................................... 12. Is administrative approval needed ................................... 13. Is conductor string provided ........................................ 14. Is enough cement used to circulate on conductor and surface ......... . (4) Casg. '~ /~-~O 15. Will c~ment tie in surface and intermediate or production strings ... ~° 16. Will cement cover all known productive horizons ..................... ( 5 ) BOPE ~ Additional Requirements: 17. Will surface casing protect fresh water zones ....... - ................ ~ 18. Will all casing give adequate safety in collapse, tension and kurs. t.. ~ 19. Does BOPE have sufficient pressure rating - Test to Approval Recomnended: Z ood) psig .. ~ Geology: Engine~ring: rev: 03/05/80 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this ' nature is accumulated at the end of the file under APPENDIX.' .. No special'effort has been made to chronologically organize this category of information, LIS TAPE VERIFICATION LISTING bVP OiO,HO1 VERIFICATION LISTING PAGE ** REEL, HEADER ** SERVICE NAME :SERVIC DATE :81/08/11 ORIGIN : REEL NAME :REEL ID CONTINUATION # :01 PREVIOUS REEL : COMMENTS :REEL COMMENTS ** TAPE HEADER SERVICE NAME :$ERVIC DATE :81/08/11 ORIGIN :1070 TAPE NAME :62061 CONTINI]ATION # :01 PREVIOUS TAPE COMMENTS :TAPE CO~MENTS ********** EOF ********** ** FILE HEADER ** FILE NAME :SERVIC.O01 SERVICE NAME VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE ** INFORMATION RECORDS ** MNEM CONTENTS : WN : SRU 31-]3 WD FN : SWANSON RIVER RANG: 9w TOWN: 8N SECT: 33 COUNt KENAI STA~': ALASKA CTRY: U.S.A, MNEP CONTENTS PRES: NEDIT4F ** RECORD TYPE 047 ** [JNI~ TYPE CATE SIZE CODE 000 000 014 065 000 000 012 065 000 000 014 065 000 000 002 065 000 000 002 065 000 000 002 065 000 000 OOb 065 000 000 OOb 065 000 000 006 065 [INIT TYPE CATE SIZE CODE 000 000 007 065 LVP 010,H01 VERIFICATION LISTING ** RECORD TYPE 047 ** RECORD TYPE 047 ** CO~ENTS ** ************************************************ jOB # 10707,6206! OIL RUN #1, LOGGED 22-MAY-81 BOTTOM LOG INTERVAL TOP LOG INTERVAL CASING-LOGGER BIT SIZE TYPE HOLE FLUID DENSITY VISCOSITY RM ~ SEAS, TE~P, RMF ~ SEAS, TEMP, RM ~ BHT MATRIX SANDSTONE 2527 FT. 90 FT, 10.75 IN. ~ 90 FT. 9.88 IN, FGM 10,4 7t 8.12 ~ 65 F 6.9 @ 65 F 5,0l ~ 105 F ************************************************ ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPP CODE 4 I 66 ~ 4 73 ENTRY 1 60 P~GE LYP 010.H01 VERIFICATION LISTING PAGE 9 4 65 U 1 66 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE [INIT API AP1 API API FILE ID ORDER # LOG TYPE CLASS MOD NO. DEPT FT 0 0 0 0 0 SFbU DIL O~M~ 7 0 0 0 0 IbM DIL OH~ 7 0 0 0 0 ILD DIL OHM~ 7 12 46 0 0 SP S01 MV 0 1 0 0 0 GR DIL GAPI 7 31 32 0 0 NPHI FDN PU 42 68 2 0 0 RHOB FDN G/C3 42 35 1 0 0 DRHO FDN G/C3 42 44 0 0 0 CAB! FDN IN 42 28 3 0 0 GR FDN GAPI 42 31 32 0 0 NRAT f'DN 42 42 1 0 0 NCNb FDN 42 ]4 92 0 0 FCNb FDN 42 34 93 0 0 SI .lIN Z~ 4 4 4 4 4 4 4 4 4 4 4 4 4 4 PROCESS LEVEL 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SAMPLE 1 ! 1 1 1 1 1 1 1 1 1 1 1 REPR CODE 68 68 68 68 68 68 68 68 ** DATA ** D£PT 2566.5000 SFbU SP -999,2500 GR DRHO -0.0127 CALl NCNb -999.2500 FCNh DEPT 2500.0000 SFLU SP -7~,5862 GR DRHO ,0066 CALl NCNb 206.0086 FCNL DEPT 2.400,0000 SFLU DRHO O. CALI NCNL 198,7124 FCNL DEPT 2300,0000 $~LU SP -49,1379 GR DRHO -0,0011 CALl NCNb 194.8498 FCN'L DEPT 2~00,0000 SFLU SP 74,4828 GR. DRHO 0.0046 CALl NCNb 241.6309 FCNL DEPT 2100,~000 SFLU SP -68. 172 GR DRHO -0,0088 CALI NCNL 2~3.6051 FCNL DEPT 2000,0000 SFLU -999,2500 IbM' -999,2500 NPMI 8.2597 GR -999.2500 20,3612 ib~ 3,2000 NPHI 11.6364 GR 56.~5~4 18,5956 IbM 58,8000 NPHI 11,i169 GR 52.7897 9,7739 IbM 69.~000 NPHI 11,1169 GR 36,9099 16,5680 ILM 58,0000 NP~I ~0.3896 GR 69.0987 18,~.429 IbM 51, 000 NPHI 11,0 30 GR 81.3½34 3.345~ -999.2500 1.1045 1.3299 18.4461 40.2560 59.6276 16.8600 43 2604 51:o54 9.5688 52.8026 58.5798 15.4103 42.1455 46.5773 16,7091 40.6906 42.7670 2.7176 RHOB NRAT ibD RHOB NRAT IbD RHOB NRAT IBD RHOB NRAT IbD RHOB NRAT ILD RHOB NRAT ILD -999.2500 2 5010 -999:2500 19,2659 2.0570 3.6260 17.8898 2,0480 3,7700 11.1885 1.9450 4.5200 16.7493 7360 11,07431 , 980 3.7400 3.3625 ~¥P OiO.HO1 VERIf'ICATION LISTING PAGE 4 ' 'sp -6o.oooo DRHO 0.0046 CALl NCNt, 212.0172 FCNI, DEPT 1900.0000 SFLU SP -1!4.5690 GR DRHO 0,001! CALI NCNL 220.6009 FCNL DEPT 1800.0000 SFLU SP -138 8793 GR DRHO ~0i0030 CALI NCNL 2~0 0429 FCNL DEPT 1700.0000 SFLU SP -142.7586 GR DRHO 0.0248 CALI NCNL 217,5966 FCNL DEPT ~600 0000 SFLU SP -124:9138 GR DRHO 0.0123 CALI NCNL 223,6051 FCNL DEPT 1500,0000 SFLU SP -125,9483 GR DRHO 0.0219 CALl NCNL 215.0215 FCNL DEPT 1400.0000 SFLU Sp -123,3621 GR DRHO 0,0021 CALl NCNL 2~5.4507 FCNL DEPT 1300,0000 SFLU -96,2069 GR ~HO 0.0066 CALI NCNL i95. 7082 FCNb DEPT 1200 ?000 SFLU SP -88.".897 GR DRHO -0,0031 CALl NCNL 209,4420 FCNL DEPT 1100,0000 SFLU Sp -93 ~621 GR DRHO 0:v239 CALl NCNL 192.2747 FCNL DEP~ 1.0§~,0000 SFLU SP 1 ,3793 GR DRHO 0,0152 CALl NCNL 212.4464 FCNL 65.4000 10.8571 53,2189 6.1590 60.5O0O 10.5974 57,0815 4.3203 60.6000 10.5974 60.9442 6.6335 58,800O 10.6494 57.0815 20.3612 52,7000 10.6494 58.7983 20.3612 61.5000 10 6494 53:6481 27.1738 65,3000 10,5974 58.3691. 10 8799 60 1000 12 6753 43 7768 15 ~387 58~ 000 10,0779 51,5021 15.1313 7~.5000 I .5974 45.0644 31 2632 71;0000 10,5974 60.0858 NPHI GR IbM NPHI GR NPHI GR IbM NPHI GR ILM NPHI GR NPHI GR ILM NPHI GR IbM NPHI GR NPHI GR IbM NPHI IbM NPH1 GR 46.8883 50.6734 3.8939 43,3360 54.5790 2.0199 44,6775 51,2450 5.3339 44.2240 50.2924 19,4686 43,4871 46.5773 18.9505 44,7531 50,1971 24,5956 40,8795 62.4854 11.0493 51.5555 50,5781 1~,2723 4 .0235 54.1027 15.0002 5 6922 30,2.459 45,1688 60,8660 RHOB NRAT II, D RHOB NRAT 1LD RHOB NRAT IbD RhOB NRAT RHOB NRAT ILD RHOB NRAT ILD RHOB NRAT I bD RHOB NRAT ILD RHOB NRAT ILD RHOB N'RAT ILD RHOB NRAT 2.0330 4.2100 4.7518 2.1680 3,8840 2.5836 2.1510 4.0440 6.3914 2.0750 3.8860 20.5778 2,0850 3,8120 20.0756 2 1050 3:9560 26.5617 2.1680 3.6600 12,6593 2,1540 4.3260 4533 I '0960 . 4.2660 17.3102 2 170 , : ooo 2220 3.8880 bVP OIO.HO1 VERIFICATION' LISTING PAGE 5 DEPT 900.0000 SFLU SP -84.5690 GR DRHO 0.0181 CALl NCNb 222.7468 FCNL 24,0121 IbM 67.0000 NPHI 10.3377 GR 59.6567 DEPT 800.0000 SFLU SP -79,3966 GR DRHO 0.0162 CALl NCNL 198,7124 FCNL 12,4144 IbM 71.5000 NPMI 10,4935 GR 50.2146 DEPT 700.0000 SFLU SP -88.9655 GR DRHO 0.0066 CALI NCNb 204.2918 FCNL 22,4792 IbM 72.8000 NPMI 10.7532 GR 51,5021 DEPT 600 0000 SFLU SP -133]1897 GR DRHO 0.0165 CaLl NCNb 218,6266 FCNL 8,4256 IbM 71.9000 NPMI 11,1169 G~ 60.9442 DEPT _50.0 0000 SFLU SP -,. 9:1379 GR DRHO 0.0050 CaLl NCNb 2~8.5837 FCNL ~0,185) IbM 63.7000 NPH! ll 1169 GR 51:9313 DEPT 400 0000 SFbU SP -101i1207 GR DRHO 0 0431 CAbI 57 94 rCNL NCNb 205. . 43,4797 Ib~ 64,0000 NPHI 11,5844 GR 46,7831 DEPT 300 0000 SFLU SP '98:7931 GR DRHO 0,0027 C~LI NCNL 212,0172 FCNL 21.0441 IbM 81,9000 NP~'I 11.1169 GR 51.0730 DEPT 200,0000 SFLU 8P -115.6035 GR DRHO 0,0056 CALI NCNL 224,89~7 FCNb 68,4320 IbM 58,2000 NPH! 18,1299 GR 60,944~ DEPT 100.O000 SFLU GR NCNb 184.1202 FCNL 161.3307 53,3000 NPMI ~0,5195 GR 48.0687 DEPT 69 0000 SFLU SP -8 2 759 OR DRHO -999 2500 CAbI NCNb -999 2500 FCNL 6875 IbM 2000 NPHI -99~,2500 GR -999,2500 ** FILE TRAIt, ER ** FILE NA~E :SERVIC,O01 SERVICE NAME : 21.3001 45.2255 59.1513 12,8740 48.9857 66.9625 20.0008 48.5511 60.5802 5.3821 43.3360 58.5798 10.0992 47 2095 44,5217 46.0191 52,8643 22.2795 47,4552 73.~495 80,5908 40.0670 52.1975 85,8260 45,0743 47.4346 9~999,00()0 999,2500 -999.2500 ILD RHOB NRAT RHOB NRAT RHOB NRAT ILD RHOB NRAT lbo RHOB N'RAT IbD RHOB NRAT ILD RHOB NRAT ILD RHOB NRAT IbD RHOB NRAT RHOB NRAT 23.0921 2.2100 3.9820 15.2989 2.1570 4.1760 22.5286 2,1610 3.9360 6.1844 2.17B0 3.8220 11.8523 2.1490 4.1520 43,8930 2,1460 4,0660 25,0740 2.1730 4.2160 95.1'196 2,1780 3.7840 49.2560 2.0340 4.1820 90,~915 -999' 500 -999,2500 LVP O10,HO1 VERIFICATION LISTING PAGFi 6 VER$IOb~ # : DATE : MA×IMU~ LENGT~ : 1024 FILE TYPE NEXT FiLE NA~E : EOF ** TAPE TRAILER ** SERVICE NAME :$ERVIC DATE :~1108/11 ORIGIN :1070 TAPE NA~:E :6206! CONTINUATION # :01 NEXT TAPE NAME : COMMENTS :TAPE COMMENTS ** REEL TRAILER ** SERVICE NAME :SERVIC DATE :8~/08/11 ORIGIN : R~EL' NA~E :REEL ID CONTINUATION ~ :01 NEXT REEL N~ME : COMMENTS :REEL COMMENTS EOF ********** EOF **~*******
