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AI 0-�--O- 13Conservation Order Category Identifier Organizing wore) RESCAN DIGITAL DATA OVERSIZED (Scannable with large plotter/scanner) ❑ Color items: ❑ Diskettes, No. Maps: ❑ Grayscale items: Cl Other, No/Type ❑ Other items ❑ Poor Quality Originals: OVERSIZED (Not suitable for ❑ Other: plotter/scanner, may work with 'log'scanner) ❑ Logs of various kinds ❑ Other NOTES: BY: 7 ARIA DATE(p /S/ 1 Scanning Preparation TOTAL PAGES BY: ARIA y DATE: 1 A% /S/ M0 Production Scanning Stage 1 PAGE COUNT FROM SCANNED DOCUMENT: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: V/ YES NO A BY: MARIA DATE: �?j ," /S/ Stage 2 IF NQ IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: MARIA DATE: /S/ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) General Notes or Comments about this Document: 5/21/03 ConservOrdCvrPg.wpd '--.,. "..._A",' ~ STATE OF ALASKA ALASKA OIL AND'-GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska' 99501-3192 THE REQUEST OF ARCO ALASKA, ) INC. for an area injection) order for Swanson River) Field ) Area Injection Order No. 13 Swanson River Field Re: March 16, 1987 IT APPEARING THAT: 1. 2. 3. FINDINGS: 1. 2. 3. ARCO Alaska, Inc. (ARCO) requested the Alaska Oil and Gas Conservation Commission to issue an area injection order permitting the underground injection of fluids within the Swanson River Field for purposes of enhanced hydrocarbon recovery and disposal of non-hazardous oil field waste fluids. Notice was published in the Anchorage Daily News on February 25, 1987 of an opportunity for a public hearing on April 8, 1987. Neither a protest nor a request for public hearing was timely filed. Accordingly, the Commission will, in its discretion, issue an order without a public hearing. An order permitting the underground injection of fluids on an area basis, rather than for each injection well individually, provides for efficiencies in the administration and surveillance of underground fluid injection operations. 20 AAC 25.460 provides the Commission with the authority to issue an order governing underground injection operations on an area basis. Swanson River Field constitutes a compact "project area" which can readily be described by governmental subdivision. ARCO is the sole operator of underground injection activities in the Project Area. All aquifers below 1700 feet within the Swanson River Field boundary, and one-quarter (~) mile beyond, are exempted under 40 CFR 147.102(b)(1)(i) for Class II injection activities. ..... - '" " '- Area Injection O~~r No. 13 March 16, 1987 Page 2 4. 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. 5. The vertical limits for injection of fluids into the Hemlock formation for enhanced oil recovery may be defined in the Soldotna Creek Unit well SCU 41-4, Swanson River Field. 6. The vertical limits for injection of non-hazardous oil field liquids into the Sterling formation may be defined in the Swanson River Unit well SRU 32-33, Swanson River Field. 7. The strata into which fluids are to be injected will accept fluids at injection pressures which are less than the fracture pressure of the injection strata and their confining formations. To ensure that fluids injected are confined to injection strata, the mechanical integrity of injection wells will be demonstrated periodically and monitored routinely for disclosure of possible abnormalities in operating conditions. 8. 9. Injection wells existing on the date of this order were constructed and completed in accordance with regulations which conform to the requirement of 20 AAC 25.412. NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth govern Class II underground injection operations in the Swanson River Field as described in Rule 2 of Conservation Order No. 123. Rule 1 Authorized Injection Strata for Enhanced Recovery Within the affected area, non-hazardous fluids may be injected for the purposes of pressure maintenance and enhanced oil recovery into strata defined as those strata which correlate with strata found in the Soldotna Creek Unit well SCU 41-4 between the measured depths of 10,230 feet and 10,595 feet. é' .."....,. - Area Injection O~tlér No. 13 March 16, 1987 Page 3 Rule 2 Authorized Injection Strata for Disposal Within the affected area non-hazardous oil field fluids may be injected for the purpose of disposal into strata defined as those strata which correlate with strata found in the Swanson River Unit well SRU 32-33 between the measured depths of 2100 feet and 3460 feet. Rule 3 Fluid Injection Wells The underground injection of fluids must be: 1) through a well permitted for drilling as a service well for injection in conformance with 20 AAC 25.005; 2) through a well approved for conversion to a service well for injection in conformance with 20 AAC 25.280; or 3) through a well that existed as a service well for injection purposes on the date of this order. Rule 4 Monitoring the Tubing/Casing Annulus Pressures The tubing/casing annulus pressure of each injection well must be checked weekly to ensure there is no leakage, and that it does not exceed a pressure which will subject the casing to a hoop stress greater than 70% of the casing's minimum yield strength. Rule 5 Reporting the Tubing/Casing Annulus Pressure Variations Tubing/casing annulus pressure variations of more than 200 psi between consecutive pressure readings mad~when injecting under steady state conditions of fluid temperature, rate, and pressure must be reported to the Commission on the first working day following the observation. Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi, or, assuming a 0.465 psi/ft geo-pressure gradient, a surface pressure that imposes a differential pressure gradient across the casing of 0.25 psi/ft at the vertical depth of the packer, whichever is greater; but not to exceed a hoop stress greater than 70% of the casing's minimum yield strength. The test pressure must be held on the tubing/casing for 30 minutes with no more than a 10% decline. The Commission must be notified ",- --... Area Injection Order No. 13 March 16, 1987 Page 4 at least 24 hours in advance to enable a representative to witness pressure tests. Rule 7 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation; and obtain approval of a plan for corrective action. Rule 8 Plugging and Abandonment of Fluid Injection Wells An injection well located within the affected area must not be plugged or abandoned unless approved by the Commission in accordance with 20 AAC 25.105. Rule 9 Administrative Relief Upon request, the Commission may administratively amend any rule stated above as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska, and dated March 16, 1987. Commission ~?// ~_. , '/ ...' / ! (/~, Lonnie C. Smith ~ Alaska Oil and Gas Conservation Commission lll/ U ---- W. W. Barnwell, Commissioner Alaska Oil and Gas Conservation Commission G6 Q WALTER J. HICKEL, GOVERNOR . LJ ALASKA OIL AND GAS 3001 PORCUPINE DRIVE CONSERVATION COMMISSIOiT ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 June 19, 1991 ADMINISTRATIVE APPROVAL AIONO. 13.2 Re: Amendment to Rule 6 of Area Injection Order (AIO) No. 13 to allow alternative methods of demonstrating mechanical integrity. T Wellman Regional Engineer Cook Inlet Region ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wellman: By letter dated June 17, 1991 ARCO Alaska, Inc. (ARCO), as operator of the Swanson River Field requested that the Commission amend Rule 6 of Area Injection Order No. 13 to allow oxygen activation logs, temperature logs , and noise logs as alternate methods of demonstrating tubing/casing annulus mechanical integrity in Swanson River wells. The Commission has determined that these logs when run as approved by the Environmental Protection Agency (EPA) under0 CFR Part 146.8 and the Federal Register Notice - Volume 56, Number , February 1, 1991 offer appropriate means for demonstrating mechanical integrity of an underground injection well. Therefore, as provided by "Rule 9 Administrative Relief," Rule 6 as amended by Administrative Approval AIO No. 13.1 on May 20, 1988 is further amended to read: Rule 6 Demonstration of Tubing/ Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi or 0.25 psi/ft ~ Administrative Appl ,d AIO No. 13.2 June 19, 1991 Page 2 .~ multiplied by the vertical depth of the packer, whichever is greater, but not to exceed a hoop stress greater than 70% of the casing's minimum yield strength, must be held for 30 minutes ~ith no more than a 10% decline. [As an] Alternative methods approved with certain limitations by the U.S. EPA may also be used, with Commission approval.i [,INJECTION WELLS MAY BE SURVEYED USING] they include but are not limited to timed-run radioactive tracer survey~ (RTS) [EVERY OTHER YEAR].L oxygen activation logs (OAL), temperature logs (TL) and noise logs (NL). Wells with tubing-to-casing communication, or no tubing annulus must be surveyed or logged every other year and wells which demonstrate mechanical integrity every fourth year. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests or the running of RTS, OAL, TL or NL. S.in~erel~ LC::'~ Lonnie C. Smith Commissioner BY ORDER OF THE COMMISSION dlf/AA AIO 13 TELECOPY NO: (907)276-7542 May 20, 1988 ADMINISTRATIVE APPROVAL NO. AIO 13.1 Re: Relief from Rules 4 and 5 and amend Rule 6 of Area Injection Order (AIO) No. 13 to accommodate Swanson River Unit Wells 21-33 WD and 41-33 WD. D. S. Joiner Engineering Manager Cook Inlet/New Ventures ARCO Alaska, Inc. P. 0. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Joiner.- ARCO Alaska, Inc. (ARCO), as operator of the Swanson River Field (SRF) by letter dated April 28, 1988 requested modification of AIO No. 13 rules to accommodate SRU wells 21-33 WD and 41-33 WD. These two Swanson River wells were recompleted in May 1972 and October 1971 (respectively) by cementing the tubing in place; therefore, casing pressure testing, monitoring, and reporting, as required by AIO No. 13, can not be accomplished. ARCO has asked for administrative relief from the requirements of Rules 4 and 5 and approval to use an alternative test method to accomplish the purposes of Rule 6. Swanson River Unit wells 21-33 WD and 41-33 WD had been recom- pleted by cementing the tubing in place and were operating as disposal wells approved by the EPA at the time the UIC Class II program in Alaska was taken over by the Alaska Oil and Gas Conservation Commission (AOGCC). Therefore, these wells are accepted "as is" by the AOGCC under "Rule 3 Fluid Injection Wells," item (3). As provided by Rule 9, "Administrative Relief" the operator is hereby relieved of the requirements to monitor and report tubing/casing annulus pressures under Rules 4 and 5 but must continue to monitor and report tubing pressures and injection rates as required by 20 AAC 25.432. The Commission has determined that timed -run radioactive tracer surveys (RTS) offer appropriate means for demonstrating mechan- >. ,/" . <'Administrative Aplh.úVal AID No. 13 May 20, 1988 Page 2 -.... '-.. ical integrity of an underground injection well. Therefore, as provided by "Rule 9 Administrative Relief", Rule 6 is amended to read: Rule 6 Demonstration of Tubing/Casin~ Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, but not to exceed a hoop stress greater than 70% of the casing's minimum yield strength, must be held for 30 minutes with no more than a 10% decline. As an alternative, with Connnission approvalt injection wellsrnay be surveyed using timed-run radioac't1ve tracer survêy '(RTS) every other year. The Commission must be notffiedat least 24 hours in advance to enable a. representative to witness pre&sure tests or the runnin~ of RT?s. G:S. )ereJ.Y~)/" ~/" ./ , ¿I/") I'll / /i. ' . .,' I' '" f ilL ", ,.. /" -- . ,7{ U;(:" U/,f/ ~ . f~at erton Chairman --/ , f? ~~OVVL'~( ><J~vtd Lonnie C. (Smith Commissioner W. W. Barnwell Commissioner BY ORDER OF THE COMMISSION dlf:3.AA AIO 13 r" ARCO Alaska, Inc. Post Office BoA 00360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 ~ RE: Administrative Relief for SRU 21-33WD and SRU 41-33WD. Swanson River Field 'êõMM'" ~~9K~M CdtvfM' ~ES ENd' I -, sn ENG---I--- C"'~ /ill ;::1"1 EN(~.,¡~ ~Nc:...- -!ß _~~_':='_E()L/ .~!! E?,~OCI- -§;-Ä~:W ~~~.rn:c¡:;¡- -~.!.~ T TECA~f ., F/I Ë:---"---'; '_.::'..:t4¡ð ~~ I ~ ~ ./Æ/C'/ /c.õ David S. Joiner Engineering Manager Cook Inlet/New Ventures April 29, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: ARCO Alaska, Inc. requests Administrative Relief under Rule 9 of the Class II UIC Permit for Swanson River Field water disposal wells SRU 21-33WD and SRU 41- 33WD. For mechanical reasons these wells cannot comply with Rule 4 (Monitor Production Casing Pressure) and Rule 5 (Report Production Casing Pressures Monthly) of the UIC permit. The tubing is cemented in place in both wells and therefore, pressures in the tubing/production casing annuli cannot be obtained. The tubing was cemented in the SRU 21-33WD in May, 1972 and in the SRU 41-33WD in October, 1971. Injection into these wells was approved by the EPA prior to the January, 1986 change of UIC permitting authority to the AOGCC. AAI therefore asks for a variance under Rule 9 from the requirements of Rules 4 and 5. In addition, an alternate testing method is also required to comply with Rule 6 of the UIC permit. Rule 6 requires the demonstration of the mechanical integrity of the tubing/production casing annulus through pressure testing. Because the tubing/pro- duction casing annuli are filled with cement, pressure testing cannot be performed. An alternate method is a "timed-run" radioactive tracer log run in the tubing. This method was approved by the EP A on December 10, 1987 as set forth in the 52 Federal Register 46837, et seq. AAI therefore requests a variance from Rule 6 and approval of the substitute methodology for mechanical integrity testing. If there are any questions or you wish any further details, please give me a call at 263-4724. \1"',; '.f,-,. .. U ~" ," t, '. iP. \,., ~:.. i - Sincerely, £VV ,~~ ~ I\~f>\j" , ¡Víí-\ 1 v J.~ D. S. Joiner 1\' \"", ('\if /) Gas Cons. Commiss\n1 ,...,as.", ",' Ct DSJ:MLE:ch:OOO7 cc: J. Dygas, Bureau of Land Mgmt. F. Hallmark, Chevron U.S.A., Inc. W. D. Kirchner, Marathon Oil Co. S. Lambert, UNOCAL Corporation ARCO Alaska, Inc. is a Subsidiary of AtianticRichfieldCompany ,""" '~ '-" j-"" Telecopy No. (907) 276-7542 July 24, 1987 Harold M. Scott Environmental Engineer Environmental Protection Agency Region 10 1200 Sixth Avenue Seattle, WA 98101 Re: Inventory of Injection Wells Dear Mr. Scott: Per your recent, request attached is an inventory for the Swanson River Field, Area Injection Order #13, which is the last AIO we have issued. The inventory sheets for Ala's 1-12, as updated in February of this year, are still valid. If you have further questions, please call me at (907) 179-1433. Sincerely, Æk/kl~lAOO Blair E. Wond~~~ Sr. Petroleum Engineer j o/A.BEW. 65 Attachments ôEPA Please print or type with an ELITE typewriter in the shaded area only, INSTRUCTIONS ON REVERSE, U.S. ENVIRONMENTAL PROTECTION AGENCY OFFICE OF DRINKING WATER INVENTORY OF INJECTION WELLS (This infonnation is collected under the authority of the Safe Drinkinll Water Act.) IV. FACILITY NAME AND LOCATION C A. NAME 1~1,~~I~MJlsbWIIRIJllIl~IRIIFiJI~LIDIIIIIIII_111111111111IIIIIIIIIIIIIIlo C B. STREET ADDRESS OR ROUTE NUMBER oI2wl,ITI,.I/IAJII,.17WllJel~IJ ~llrtRINIIRI61~ I1III 14~16 - 45 C C. CITY OR TOWN D.ST. E. ZIP CODE OI3Sl€wl~~If)IIKI~~I,loI/l4kallllllllll AIK III I 141516 - 4041424~- - 47 V. LEGAL CONTACT: TYPE, NAME, PHONE, MAILING ADDRESS, AND OWNERSHIP i ~;¡,:=;~::::: ~.wll~"~~ I ulolHI~ ~ITÎlïIJTïTTT IIII 11I1 II III L~ld;I;I~ï;¡;¡;~~ C . D. ORGANIZATION - OI5AIRlcbll.4ILWlslk~I)IJWlcl.111111111111111111111111 14'~16 - 5~ C Eo STREET OR P.O. BOX OI6~,lol.~o)'ll/ldoI3~k) I / III!IIIIIIII,I 141516 - 45 C F. CITY OR TOWN IG. ST.I H. ZIP CODE Form Approved OMB No. 15S-RO170 III. TRANSACTION TYPE ('X' one)' U I. DEL.ETION .i'!2. FIRST TIME ENTRY 03. CHANGE OF ENTRY 13 ' " F.COUNTY G. INDIAN LAND (mark 'X') ) 1~1:5-1~lclMrl~~I'E11 I IJ I I I II I II I I L~3~~1 ~ VI. WELL INFORMATION I. OWNERSHIP('X' one) 0 M. PUBL.IC U O. OTHf:R (specify) 52 52 KF. FEDERAL. ) UC = UNDER CONSTRUCTION AC = ACTIVE TA = TEMPORARILY ABANDONED PA = PERMANENTLY ABANDONED AND APPROVED BY STATE AN = PERMANENTLY ABANDONED AND NOT APPROVED BY STATE WELL OPERATION STATUS: C A. CLASS AND TYPE ~~ ~~ 14 15 16 17 ~-L 14 15 16 17 ~-L 14 15 16 17 !k-L 14 15 16 17 ~J, ~rl- EPA Form 7500-48 (11-791 C. WELL OPERATION STATUS B. TOTAL NO. OF WELLS AN D. COM~1 EN TS (optional) UC AC TA PA Ill" II 1l5-11 II II 181 i,l;' 221-(4251~1;281-13O311-1~~341-(6 IS, ï ( 22¡-(425,-(281-r311-(334-f6 18, ï (' 22,-(425,_/2728/_(°31,-(334,-,36 181 ï 121 221- 124 2s,-(728,_(031_,3334,_(6 181 ï 12\ 221- r25- (281-13031 1-1:<334,- (6 18 - i' ¡Z2 - 24 (5 - 27 28 - 3031 - 33 34 - 3<; J!?1 2J- 124JJ272JJ3031IJ333J_I'6 .11/ n ':Ir I? r-'e ,..--- Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of ARCO Alaska, Inc. (ARCO) for an area injection order for the Swanson River Field. The Alaska Oil and Gas Conservation Commission has been requested, by letter dated February 6, 1987, to issue an order for area injection to provide authorization for utilizing service wells permitted in accordance with 20 AAC 25.005 or 20 AAC 25.280 to inject fluids underground for the purposes of enhancing oil recovery and disposal of non-hazardous wastes in the Swanson River Field. A person, who may be harmed if the requested order is issued, may file a written protest, prior to March 12, 1987, with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501 and request a hearing on this matter. If the protest is filed timely and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 AM on April 8, 1987, in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after March 12, 1987. If no such protest is timely filed, the Commission will consider the issuance of the order without a hearing. tN. W. w. W. Barnwelli' Commissioner Alaska Oil & Gas Conservation Commission Published February 25, 1987 . STATE OF ALASKA ADVERTISING ORDER /' F R 0 M Anchorage Daily News P. O. Box 149001 Anchorage, Alaska 99514-9001 T 0 p U B L I S H E R Alaska Oil & Gas Conservation Ccmnission 3001 Porcupine Drive Anchorage, Alaska 99501 ----"^ ADVERTISING ORDER NO. AO- 08-5585 AGENCY CONTACT DATE OF A,O, Gal yn Evans PHONE February 24,1987 (907) 279-1433 DATES ADVERTISEMENT REQUIRED: February 25, 1987 SPECIAL INSTRUCTIONS: AFFIDAVIT OF PUBLICATION UNITED STATES OF AMERICA STATE OF ~ ~ ~ 55 DIVISION. BEFORE ME, THE UNDERSIGNED, A NOTARY PUBLIC THIS DAY PERSONALLY APPEARED ~ ~ WHO, BEING FIRST DULY SWORN, ACCORDING TO LAW, SAYS THAT HE/SHE IS THE ~+~ OF ~ #~ PUBLISHED AT ~~- IN SAID DIVISION ~ AND STATE OF ~ --/ AND THAT THE ADVERTISEMENT, OF WHICH THE ANNEXED IS A TRUE COPY, WAS PUBLISHED IN SAID PUBLICATION ON THE .:2~ DAY OF ~/ 19~, AND THEREAFTER FOR~ CONSECUTIVE DAYS, THE LAST PUBLICATION APPEARING ON THE ~AY OF~ 19 'n, AND THAT THE RATE CHARGED THEREON IS NOT IN EXCESS OF THE RATE CH~'GED PRIVATE INDIVIDUAL$.. r:~~ ~ SUBSCRIBED AND SWORN TO BEFORE ME THIS~DAY OFS""~"" 19ì{) "'~,~~ ~ ~ ~ .~"..,.,,~~- NOTARY PUBLIC FOR STATE Of: ^ ^~~ MY COMMISSION EXPIRES ~$6ioD~pìresJuly3tlt.O 02-901 (Rev, 6-85) PUBLISHER REMINDER- INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COpy OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. ,.' """"""~-"-" . .. ,..."-""- John C. Havard Engineering Manager Cook Inlet/New Ventures - '-'-""-"'---~-------"-""""'--7- - . -------- ---'. J1 ~ ~ . r~vv adr.... - . ~r~ #L CJíJ¿ :Y 6- ~ ..~.'- ARCO Alaska, Inc. ~.. Post Office Box 100360 Anchorage, Alaska 99510-0360 Te~phone9072656369 February 6, 1987 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Beluga River Unit Application for Underground Injection Swanson River Field Area Injection Order Application Dear Commissioner Chatterton: Attached are the ¡'eferenced permit applications. Please note that we have requested authorization only for injection through well BRWD-1 in the Beluga River Field. This is the same well previously authorized for injection by the U. S. EPA. The EPA also exempted the aquifer extending in a 1 mile radius around this well bore. An area injection order is requested for the Swanson River Field. The aquifer there has been exempted below 1700 ft: Your help and patience during the application preparation is appreciated. I f you have any questions, please contact Rod Hoffman at 265-1345. Sincerely, ~ JCH: RWH:bp 0047 Enclosu re cc: B. Wondzell, AOGCC RECEIVED FEB - 9 1981 Alaska Oil & Gas Cons. Commbsion Anchorage ARCO Alaska, Ine, Is . Subsidiary 01 AtiantieRlehfleldCompany -- /"', . .-...., SWANSON RIVER FIELD AREA INJECTION ORDER APPLICATION RECE IVED FEB - 9 1987 Alaska Oil & Gas Cons. CommissiGn Anchorage /""- .---. SW ANSON RIVER FIELD AREA INJECTION ORDER APPLICATION TABLE OF CONTENTS Section/Regulatory Citation Subject Page A. 20 AAC 25.460 Area Injection Order 1 B. 20 AAC 25.402(c)(l) Plat 2 20 AAC 25.252(c)(1) C. 20 AAC 25.402(c)(2) Operators/Surface Owners 5 20 AAC 25.252(c)(2) D. 20 AAC 25.402(c)(3} Affidavit 6 20 AAC 25.252(c}(3) E. 20 AAC 25.402(c)(4) Description of Operation 7 F. 20 AAC 25.402(c)(5} Pool Information 9 G. 20 AAC 25.402(c}(6) Geologic Information 10 20 AAC 25.252(c}(4} H. 20 AAC 25.402(c}(7} Well Logs 16 20 AAC 25.252(c)(5) I. 20 AAC 25.402(c)(8) Casing Information 17 20 AAC 25.252(c)(6) J. 20 AAC 25.402(c}(9} Injection Fluid 20 20 AAC 25.252(c}(7} K. 20 AAC 25.402(c}(10) Injection Pressure 25 20 AAC 25.252(c)(8) L. 20 AAC 25.402(c}(1l) Fracture Information 26 20 AAC 25.252(c)(9) M. 20 AAC 25.402(c)(12) Formation Fluid 29 20 AAC 25.252(c)(10} N. 20 AAC 25.402(c}(13} Aquifer Exemption 30 20 AAC 25.252(c}(1l) O. 20 AAC 25.402(c}(14) Hydrocarbon Recovery 31 P. 20 AAC 25.402(d} Mechanical Integrity 32 20 AAC 25.252(d) Q. 20 AAC 25.402(h) Wells Within Area 33 20 AAC 25.252(h) RWH/2 Attachment ,,--...., Title B-1 B-2 E-1 G-1 G-2 G-3 1-1 1-2 J-1 J-2 "-"', Swanson River Field Area Injection Order Application List of Figures Regional Location Map Swanson River Field Road Map Injection Well Data Contours of the Hemlock H-4 Horizon Electric Log of Water Injection Zone Electric Log of Gas Injection Zone SCU 321-9 Casing and Tubing Detail SRU 32-33 W.D. Casing and Tubing Detail Gas Analysis Report Wake Analysis Report Page 3 4 8 13 14 15 18 19 23 24 RECEIVED fEa - 9 1987 Alaska Oil & Gas Cons. Commission Anchorage ~, ¡-- SECTION A Area Injection Order 20 AAC 25.460 ARCO Alaska Inc., as operator of the Swanson River Field (SRF), requests an area injection order be issued for current and proposed injection wells: 1) for disposal of fluids that are brought to the surface in connection with conventional oil and gas operations and commingled with non-hazardous waste fluids from facilities which are an integral part of production and operation, and 2) for the enhanced recovery of oil or gas. The area injection order is requested to encompass all lands within the boundary of the SRF which includes all participating areas of Swanson River Unit and Soldotna Creek Unit. ARCO requests that the order allow ARCO to drill, operate, convert or plug and abandon wells within the SRF by filing Form 10-401 or Form 10-403. The Oil and Gas Conservation Commission may, in its discretion, issue an area injection order if certain requirements are met. The SRF injection operations meet the requirements of 20 AAC 25.460(a). Existing wells are described and identified by type. Injection wells are within the same field, are operated by a single operator and are used for other than hazardous waste injection. The cumulative effect of drilling and operating additional enhanced recovery injection well~ will result in an increase in hydrocarbon recovery. The cumulative effect of additional fluid disposal wells has been reviewed and additional wells operated in accordance with Commission rules will not initiate fractures in the confining zone or cause migration into fresh water strata. Both types of injections wells will be drilled, constructed, operated, and abandoned in accordance with the Commission rules to prevent movement of fluids into fresh water strata. -1- ~ . .-.., SECTION B Plat 20 AAC 25.402(c)(l) 20 AAC 25.252(c)(l) Attachment B-1 is a regional map showing the location of the Swanson River Field relative to general Cook Inlet geography and other fields in the area. Attachment B-2 is a topographic map of the Swanson River Field (the Area of Review) and contiguous areas on which is shown the location of the existing wastewater and gas injection wells. Also shown on this map are the locations of waste storage facilities, surface bodies of water, and all water, gas and oil wells in the area. RWH/2 -2- '\AJ y.- ~ .-, J ( "- riJ~ 4--1 ~ #- # ~~ ~ <f ~ , '" '" '" '" <:.':t ",-,,4' ~..::t <.,:,'3~ -<""'t ~ i FIRY ISLAND ~~ 'ò~ <& 4-1* ~ 4-# ~.. ~ '(' ~ /' 'i.~/' ~ \" /' ~'?, /' *' ~ /" ~ ~ '\,,'}) '\' ,\,'1J <t .<.."1J .<.."1J \ .<..' '" ~ 0 0 ,4-~ :\~ ~.. ~ ~ ~ ~ ~ , '" /, ' ,,""~ C ,~ ~ ,~ ,,~ <.' "", ",' -\' ~~ '" ~ -<..,f:> 4--t /' ~ ",,(3 ~ # <f " <.~~ 4f " ~~ ~ O~ ~ SWANSON RIVER FIELD ~~~ " ~~. ~ ~~ ~ '" $ D 'ò" '(' " -\'ò~ ~ ~, #~. ~~ " ~ .(j.'t" <'" a <J, [f '~ 61° Q ~# '" -\~ pft::Y «' /' <-'t ~ <f '" ",':o~ ~~ , -<..'ò~ ~ ¿! ¡p 4-~ /' \~ <Þ~ '" ~ A.",~ ~ ~ , o~ ,," . - J'---- . " "'~ . 4-q. ~# 4>' ~ ~ 4>' 4-'!t '" .{b't- 4-# /' ~~ ~ /' ~'t- ~.. ~ '" 4t '* ~ 4f ~ <f '" /' " 4' <-~ ,(I't 5 0 5 , I I SCALE IN MILES ! SWANSON RIVER UNIT COOK INLET AREA ATTACHMENT B-1 A600387001 Rt -3- ~ .,..-.." SECTION C Operators/Surface Owners 20 AAC 25.402(c)(2) 20 AAC 25.252(c)(2) The surface owners and operators within the area of this area injection order and extending 1/4 mile beyond the boundary are: 0 ARCO Alaska, Inc. 0 Chevron U.S.A., Inc. 6001 Bollinger Canyon Road San Ramon, California 94583 0 Marathon Oil Company P. O. Box 102380 Anchorage, Alaska 99510 0 Unocal P. O. Box 190247 Anchorage, Alaska 99519 0 U.S. Department of the Interior, Fish & Wildlife Service P. O. Box 2139 Soldotna, Alaska 99669-2139 -5- /",""" -.., SECTION D Affidavit 20 AAC 25.402(c)(3) 20 AAC 25.252(c)(3) Affidavit of Roderick W. Hoffman STATE OF ALASKA THIRD JUDICIAL DISTRICT I, Roderick W. Hoffman, declare and affirm as follows: 1. I am over 19 years of age. I am employed by ARCO Alaska, Inc. as a Senior Environmental Coordinator. I have personal knowledge of the matters set forth in this affidavit. 2. On h b (v()J~ ~ I--k. , 1987, the surface owners/operators listed in sed'tion C were provided a copy of this permit application. DA TED at .,;:- rC \..i '" cJ. "(j Anchorage, , 1987. Alaska this ~\'t-~ day of fl ¿ 'c f ~ &!r t---- Roderick W. Hoffman Subscribed and affirm ed before me at Anchorage, Alaska on Ft~ ~ , 1987. ~~;?l~~~ State of Alaska My commission expires:(:;-3-90 -6- -- ..-., ATTACHMENT E-l Injection Well Data Water Disposal Avg. Max. Avg. Max. Depth of Depth of Wells Rate(BPD) Rate(BPD) Press(psi) Press(psi) Inj .(ft.) Well(ft.) SRU 31-33W 3274 4500 769 1000 2100 2461 SRU 32-33W 651 4500 778 1000 2100 2520 SRU 41-33W 125 4500 913 1000 ~~$2 3000 SRU 21-33W 2805 4500 735 1000 2.1 ~Q 38Q~ SCU 43-4W 4500 Shut In 1000 3100 6660 Gas Injection Ave. Max. Wells Rate(MCFD) Rate(MCFD) SCU 314-2 39,950 45000 5075 5800 10291 11520 SCU 323-4 35,680 45000 5370 5800 10394 10775 SCU 332-4 27,640 45000 5095 5800 10470 11119 SCU 341-4 37,640 45000 5355 5800 10226 10850 SCU 341-'8 30,300 45000 5160 5800 10256 10814 SCU 312..:9 44,000 45000 5270 5800 10183 10785 SCU 321...9 29,940 45000 5155 5800 10294 10745 SCU 323.9 35,920 45000 5105 5800 10280 10750 SCU 343-33 0 45000 Shut In 5800 10695 10995 SRU 332...15 0 45000 Shut In 5800 11388 11982 SRU 312.:.22 0 45000 Shut In 5800 10754 11000 SRU 314-27 0 45000 Shut In 5800 11146 11434 SRU 331-27 0 45000 Shut In 5800 10804 11620 -8- ~ --- SECTION F Pool Information 20 AAC 25.402(c)(5) The Swanson River Hemlock Oil Pool is defined by Rule 3 of the Conservation Order No. 123 as the strata that are common to and correlate with the accumulation found in SCU well 41-4 between the measured depths of 10230 and 10585 feet. RECEIVED FES - 9 1987 Alaska Oil & Gas Cons. Commission Anchorage -9- ,~ ~ SECTION G Geologic Information 20 AAC 25.402(c)(6) 20 AAC 25.252(c)(4) Introduction Swanson River Unit was formed in 1956 and Soldotna Creek Unit in 1959. Early delineation drilling revealed that the two units covered the same reservoirs, so an agreement was made in 1963 to operate all participating areas in both units as Swanson River Field. Production is allocated in fixed percentages to the two units. Cost allocations are also fixed. Operationally, the two units are treated as a single entity 'Swanson River Field,' which is run by ARCO. The stratigraphically oldest and deepest strata produced or used for injection at SRF is the Hemlock Fm, Oligocene age. Production from the Hemlock has been enhanced by pressured maintenance programs which were initiated early in the field's history. Gas injection is currently used to maintain pressure; water injection has been used in the past. Younger strata present at SRF are represented by the Tyonek Fm (Miocene age), Beluga Fm (Miocene age), Sterling Fm (Piocene age), and undifferentiated Quaternary deposits of glacial silts and gravels. Sandstones of the Sterling Fm are used for disposal of produced water and drilling fluids. Numerous sandstones within this section are also gas productive. Geologic information on the zones used for injection in SRF is submitted in the following subsections: Subsection 1: Subsection 2: Sterling Fm Hemlock Fm -10- /"< -.. Subsection 1 Sterling Formation The current water disposal wells are injecting into the lower Sterling Fm. In SRF the Sterling Fm ranges in depth from approximately 500' to 3,500'. 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'. Individual stands tone thicknesses are commonly 10-50' and are interbedded with claystone, siltstone, and coal beds. The average porosity is approximately 30%. The confining zones above the Sterling Fm are interbedded sands, gravels, clays and silts of glacial origin. These sediments typically reflect poorly sorted heterogeneous mixtures of various rock types which have low permeabilities. The presence of shallow gas sands at 500' indicate the sealing capacity of these zones. Sterling Fm sandstones are fine to coarse grained, sub-angular to sub-round with fair to moderate sorting. Petrographic analysis shows them to contain more than 50% rock fragments which are predominantly of volcanic origin. Other grains consist of quartz, chert, feldspar, and minor amounts of silt. The sandstones contain little discernible detrital and authigenic matrix. The Sterling sandstones probably represent deposition by large meandering streams during Pliocene time. Some deltaic influence is suggested by the presence of diatoms. Continuity of the sandstones is fair to good based on well-to-well correlations. Approximately 50% of the injection interval is composed of sandstone. Claystones range in thickness from 1'-15' and are medium gray, massive, and firm to hard. The presence of gas sands in the lower Sterling Fm testifies to the ability of the claystones to seal. In addition, water shut-off tests in well SRU .41-33 indicate little or no vertical permeability. R E ( E I V E D fEe - 9 1987 Alaska Oil & Gas Cons Comm' . . IS8m" Anchorage Subsection 2 Hemlock Formation The Hemlock Fm is the main pay zone at Swanson River Field. Gas is currently injected into all known oil bearing intervals of the Hemlock to maintain reservoir pressure. All currently operating Hemlock injectors are located in Soldotna Creek Unit. -11- -" _.~ I '- At SRF the Hemlock Fm occurs at depths between 10,000' and 11,500'. The formation consists of conglomerate and fine to coarse grained sandstones interbedded with coal and carbonaceous claystones. Ten distinct sandstone-conglomerate intervals are recognized within the Hemlock Fm forming the basis for formational subdivision into H1 through H10 members. Net oil sand thickness within these members vary from 10 to 90 ft. with an average value of 36 ft. Average gross thickness is about 400 ft., and average porosity is 21%. The oil accumulation at Swanson River is localized by a doubly-plunging anticlinal fold whose culmination is in Sec. 4, T7N, R9W (within the SeD). The fold is generally aligned north-south. Faulting in the field consists of a series of up-to-the-south, normal, tensional, low angle faults whose axial traces trend east-west orthogonal to the trend of the anticline. The faults control production to some extent and exhibit several periods of movement. Generally, they decrease in displacement downward and easterly. Over 1,000 ft. of closure is present in the SRU at Hemlock depth, yet the oil column is limited to slightly over 200 feet. The SRU is separated from the seu to the south by Fault E (a 300-500 ft. displacement fault believed to be a significant fluid barrier), and the seu is broken by numerous up-to-the-south normal faults which elevate and broaden this area giving it a somewhat bulbous shape in plan. The oil column in SeD is +/- 600 ft. The anticlinal axis migrates eastward with depth. Confining zones stratigraphically above the Hemlock are claystone and coal beds of the Tyonek Fm. The presence of the oil and gas accumulation in the Hemlock Fm indicates there excellent sealing capacity. Pressure differential between Hemlock members indicates excellent sealing capacity for interbedded claystones within the Hemlock Fm itself. Accompanying Section G are: Attachment G-1 showing the structural configuration of the Swanson River Area at the top of the Hemlock H4 horizon; Attachment G-2, an electric log showing the water injection zones in a typical water injection well; and A ttachm ent G-3, an electric log showing the gas injection zones in a typical gas injection well. -12- ,~~~:~:_"-,-~. , ,----L_--þI, I' I I ~ ~ I -1-=- T~ ' 't-~ ¡ F-f1;51 ~ I r"" ~.;: , ~ -~ ~ , , . , J "\ ,:.. ~c( ( ~- ~- ~r ~~ (~) _I ? ~... . ~ <. :~ r ~~ t=: .~ I .' ~ ~ '- -- ~ ,-- s '.. ¿->,"JI!;¡ ~ - ~.t.. ~ --~ -/' ~,. oW ~.... J-~ ~ 4/', ~...-J, \ ~ ~' '. ~ ~ , -- - . ~ '~ -.; .,; ~. ~~ {" '...~,.. 'o\' ~ ~a :y: t, ~ .I 't t ... ' SPOHr AHEOUS -POTOO1Al . I 50 ~ 0 0 , 1,1lJ ~ f, ~ ~ ... 0 0 0 t> -J } ~ ... Õ 0 c ... $ (: S ... ... 0 0 ~ ~ .J .~ ~ .~ f "' J it A ... !) 0 ... ... 0 0 ~ ' j ~ . """"-- c ~ ".-v1Y'~ (OHDUŒVITY 1000 ~ OON~UcrI.I~ MlWMHOSM== DEEP INDUCTION ;00 :-14- :,:t::= Cfo(Ev~~ USA ~N. Þ ~.R.u. 3l.33 >- $wANS~ J(h/~ ,:¡~ \, ALASKA < ,.... ) ( ;> t') ALL "STMLI,.J, ~os \ { 0" I ~Nj'lcTtoN ~ :r~vAl '1 { "" / I CICIO ~M'/M Attachment G-2 Electric Log of Water Injection Zone 0 'J~>t I 1 '/~" ~ ~. ~J í Î ~ . (j , ,"" j' y---"--' " - ( -- , .""""""'~ ~.... "'.,""P4'~' .~;;;~.':~: .." 1(,~b3 I _..~ "'5" .- ~ " .i! ,? . . -;.( I I,,' ,'" - ~ .~- -. ..,-, ~ :.::,::;~t ' ~ ,," "c- 0 \; . ~.-~ -, :'::':'.~:':'::' r-"~ . .l.~~', ~ I ::'::: ..;, en .... - ~;Jrc ;:..... "'s":'" h. -~ -- r- . "^ ,.. . ., ~ . '-64' "~ ì'" s"'" I.' .. - ~- -?i'"...'i ~;:\,;:,~:~;,~: - in .....' -'(I ",..,,"" -.. -. ,- '" s ~-- -.:lJtI+" ~ ""'~"" - u- cc t ~ ';;;;:::'ë:., ~"'~..,- ~ .. - '~ I~~;~' loH~~ -N>- "t ~~.:~._' ~ ~ tr:l.. ' """ - 'J: -- . -- H'5 ~- ~- t:.:.:.....~o- . . - ~ ... IG:,...I. ... -- ~ .~.1t---- ~ {O' ":':'17'~~ '"" . ' . ~ .,1" "" r... - . ..,s ~- -- -~- ' 1'11...." . . -74' , ~ i..=. -- ..., ,t:., ' ,i~T~-~-- . -Er. 0: ," - - --. ~ ~ tJI".'. ' IO~ '~-_, ~~~}g¡(- ~ ~ ::::;;:::.'i'~- -~ . - ,~ . '~¡!¡¡~ ~1 .~ ~ .- ~,'.' ~ ~l..:.,j~~~i.~:. ~~~.~~:~ ~ .'.'::::~: , ~. . "'" "'s' " ." -- -Y'I -- ~~ ~ .'-e?'.~ "i'~ ~ --9,4' ~ g;~¥-~ ~- ~ .,'~~ ~-' ~ ~~ ~ ~,--. =" . ~ ~ ~ ~ ; '.' ~ - 1:8" .-- ~QW" .~ ~- , ' t:,., .. r ~, I 0f0".Q0 .... '.. . . . . . I"~}./" ....... . . , . j~:~(. ~:5~ ~....- 0 0 ~ .. ~- , ~ '- --- ,¿ ~ .. . . . ! :i ---. , - - - ~ ,. :( .~ -- 1 . , ~ I . .~ -- ---. -. -, c:::¡:;, .. - '-!J5=- -- ~ ,---- KIO -~ .-.,---- ~- -. , t- -.-- _.~-_. , -~-_o%- " 11 ~ -+--- . - , _.f" 1- , -Sð--: --:ið ,/Ç-. 7f3' r. - <5- ~ - " SCù 2.\-~ Eft\J: I~'Z.' Kß 1'.1. I , IO74~ ){ß: '\.0. ~ 'SVlAf.'SfH '<hlf(. fiEi,O A~A \ I,., 3"~T"~ 'Sþ,JT~vA(. At+ HfMuO( ~,.,o j I , Attachment G-3 Electr ic Log of Gas Injection Zone ,~ ~, SECTION H Well Logs 20 AAC 25.402(c)(7) 20 AAC 25.252(c)(5) All openhole logs from wells in the SRU are sent to the Commission as the logs are completed. Type logs for the SRU are included as Attachments G-2 and G-3. -16- ~, SECTION I Casing Information 20 AAC 25.402(c)(8) 20 AAC 25.252(c)(6) ~, Typical wells are cased as shown in Attachments 1-1 and 1-2. Attachment 1-1 shows the typical subsurface details for a gas injection well and Attachment 1-2 shows subsurface details for a typical water injection well. API casing specifications are included in each drilling permit application. All casing is cemented in accordance with 20 AAC 25.252(b) and tested in accordance with 20 AAC 25.030(g) when completed. In wells converted to injection, the casing is retested in accordance with 20 AAC 25.412(c). -17- ~. ",0 .Uõ ! \I1 . ""'4' "'~ /~l1 I :( ,:' : = ,: a. . --;r' : ~ ::- -....:~ .-, ~,<II ~ 9,6$7 .s.' - 317 JTS. 3h' 48 MODifiED 81æ 9.3,rr N-80 m 9638.39~ . \".¡ ....i._~ ug 9,658.04'- , 1.. <, :':---, ':. >~ b X.{)VER 3~Zt21e 48 wQOtFIED 811D ,50' "'.,. I . ->---.~, Q"'~ 9,713.00'- TOP Of LINER r :( ¿~: -,' - = 10,""0'- II HI. 2 ~. Ai MODIfiED I" ',80 '.1'IIT 11'. I. .. -- :f -. ~ ;.~ - 10,200.06'- CANCO 2 h. AS MODifiED "-BMb MAI()REL 1/ EI VAlYE ~ - . "i. - 10,231 .4"- I JT 2~' 4B MODIFIED 811D 11.80 411FT. TBC ,j I r?- .: ~ & & =::::::::= :~~ER/:,~'I':~;":'E: ~::E~" 411FT. m, =---"')1 ,;:,\. . -'. .-'C,'U."'- GTls"s"MI"lE POSiTlGII ¡ --'--111 ',' I L. ~-:----Cd' " ::::: : -'O,",."- ¡ JTS, 1\i '8 NG\)I"E1)8RO I.BO um m. -\- , I - 10,374.34'- CAMCO 2 h' A8 MOOlfiED "8N' MANDREL r- . 10,324 : E :-.:>{ I 7,Jj..: : " ., :~::'.~ ¡ -10."'."'- ~~fHT:'J;Al:!I' II MODIfiED ." tl .~~ 10,31S" .J ..~' ~: ~ -IO,377-S4'- I PUP J1 23/8" 4B MODIFIED 8AD 11-80 4.1,Ft ... J t :g g -10,383.79'- 8UER 5h'x 2J., f.1l PACHR --,,:,:-j ':::', ---~ 10,31" -10,408-74'- 3 PUP JTS. di AB MODIFIED 8AD 11-80 um ,-. ~ I., ., -10,410.27'- 01IS's'NIPPLE POSITION Z =: '-'- -~ r: : ' -10,441.97'- IJT.2;S'AB WODIFIED 8AD NO 4.7'hr. m, ~-~.. r' ' I -lo,45l.eo'- CAWCO 2;8' A8 WODIFIED KBMC ICANDREl ;,- Jill']O I~, . i . ...:~' flTH EI VALVE ~ ~ ~ ~ tt -:~ -.--:$ - 10,454.2" - I SAFETY JT, 23/i U NODI FlED BROWN CC : ~ I ;.1 lat ~ --'~ ~ -IO,4!H\7"- I PUP JT. 2;"MODlfIED 8RD HO 4.7.1FT. ..~ I ¡ 10.4~': :g -'°,462.01' - BAF,ER sYz'x de' F.H. PACIER È. c '--1:'J.~uJ.u, II ¡ . '°,474' -10,491,99'- I JT. 2;" A8 MODifiED 8AD N-80 4.7'FT, TBC ~~t ~ .. ~1 ~ I~ . : OJ -10,493-51'- 011S 's' NIPPlE POSITION I ~ =;.~ .... :.q...!..J.J! I . - IO,508.S3' - 2 PUP JTS. 2 h' A 8 MODIFIED 8RD 11-80 4.71Ft ~'T"~,~ -~i' ~_:r.:zI~'I: ", ~1/T1~1 . I' -10,540,62'- I JT. 2h' AB MODIFIED 8RD rHO U"'FT.TBC ~=t~tt'¡' 3! 111 J I ¡ ..~ -10,553.36'- WICO 2h' AB MODIFlED- WIG M4NDREL ! ~ f; '~~ I ¡ I "....' , - ,. .'" n' ...; I'~~' ¡ Ii :BAl;:Olf'EO B" '-80 4,I1n TIC, :;-, ~::¡:;:; , ,:':þ í . ,-10.,",,"'- tANCO'O'XlPI'LE ¡\.. 'ID ¡:=~ ", ~ rf- - : -10,586.00'- SUER SUB STOP 2~8' 811D .. '~ . --?f -': '~Z =:8: - 10,587 .00' - SUER 5~Z' 20'FT MODEl"D' PACKERW.L.SET t;.tP_, I; :,' ~~, - r: ~IO,m' 2-; - -IO,~91.00'- I SEAL ASSENBlY 2;" '-'- ~::. ~ . : I ~j"""'" -10,59166'- SHEAR SUB MULESHOE SlUNOSED WITH ,. ~ -- i 10,151' ~ ¡. HOlE IN CENTER {--:::t= . ~' ' on , - - W.l.SIIEDC£ AJlD SEAl ASS0I8LT FISH . '~-;-- ,', ~:. '. c. ' 'ã X -ID."" "oaf PUi' ", "." .U"KlASI I"'" "ER! ¡.¡,." ~, -. , ¡ I ,'~ ~; I '-IO145'TOTAL DEPTH SCU 321-9 rll . oM !tIL J.' uu¡mllf I NOTE: TUmC PARTIAllY DAlUCED WHilE Sec 9. T7N, R9W. S.M. I .... ..-...'-' . fI 01-. .". .. RUMNING 'N HOLE. CONSULT WELL . ,.,...~".,,_.' - T.'Ie,NI', ro- HISTORY BEFORE WOUIN; 011 WELL. TU81NG RUN 3 -21 -84 ,-, ~, --- T 00111; HA~R BORED TO A COSASCO B.P.V, I PUP Jr. 3 h' AS MODifIED 8~o N'80 , : , , . .,¡ . '.'1 f CASING a TUBING DETAIL NPB -18- Attachment 1-1 SCU 321-9 Casing and Tubing Detail mD' l.l5' 531.36' 10.66' 31.3 5' , 6.25' 30.5 9' l.5f 93.16' 10]9' 1,4Z' 1,78' 6.25' 24,95' 1.53' 3110' 10M' 1.4" 1.50' 6.30' 29.98' LSz' ISJz' 31.79' 1Z.T4' 3 Q..93' .~' .19' (Z.80 '1 5,00' ,&6' : zs' 7-9.8' -,I. , . 0 CO :~ 0 . I I I ilit-I ~I C'\, In In . .c - ~'. .r-- \ TYPE A2 TUBING HANGER 3~2' ," - * 323.7'"0.0. 3.0Z" 1.0. 2000 W.P. STAR FIBERGLASS i.P. THREADED EUE 8 RD. '&='8 - %048' - TOP OF PACKER SAKER MODEC F.I (WIRE LINE MEASUREMENT) SEAL ASSLV. WITHIN PACKER , . crt . ~I c:-.. . . ~ I w' ~. . :t100' . I au' . 11S4' . I 2278' . 2 S' c' . Z4Z4~ .7-2(1-83 ; I'- X TOP PLUG 2450' . Ja... . . T.D.2520' SR U 32. 33 W~fJ. CASING a TUBING DETAIL SECTION 33 T.8N., R.9W. SM WOItI(OVEA 8.20.81 -19- Attachment 1-2 SRU 32-33 W.D. Casing and Tubing Detail /- ~ SECTION J Injection Fluid 20 AAC 25.402(c)(9) 20 AAC 25.252(c)(7) The two types of injection at the SRU are: 1) gas for enhanced recovery, and 2) produced water separated from the oil stream and commingled with non-hazardous waste streams for disposal wells. Subsection 1 Enhanced Recovery Type of Fluid - gas Analysis of Composition of fluid The injection fluid for the gas injection wells is dry natural gas with a specific gravity of 0.61. The properties of a typical gas sample is shown on the gas analysis sheet in Attachment J-1. Source of fluid - Hemlock Formation Estimated amounts to be injected daily The average gas injection rate for the Swanson River Field varies from 200,000- 300,000 MCFD. The daily average for May 1986 was 270,000 MCFD. The maximum injection rate is limited by the compressor plant output and is approximately 305,000 MCFD. Compatibility with formation and confining zones - full compatibility - reinjection into producing zone. -20- r--"", Subsection 2 Fluid Disposal /""'--.. Type and Source - The injection fluid for disposal is predominantly produced water. The injection stream includes drilling mud, reserve pit water, contaminated crude, diesel gel, glycol, domestic waste water and workover fluids. Physical Characteristics of Injection Fluids 1.) Produced water (average weight 8.9 ppg): The produced water at Swanson River averages approximately 27,000 mg/l total dissolved solids with typical properties as shown on the water analytical report from the 1-33 waste water facility (Attachment J-2). 2.) Drilling Mud: Normally, a lightly treated Lignosulfonate with 3% KCl is used within the Swanson River Field which has the following general' properties (undiluted - average 10.0-12.0 ppg diluted 2 to 1 - average weight 8.8-9.55 ppg): Similar to type 1 mud approved by the EP A as approved mud for NPDES General permits. Material Fresh Water Benoni te Barite Potassium Chloride (KCn Lignosulfonate Polyanionic Cellulose Potassium Hydroxide Caustic Soda Acrylic Polymer (Bentonite Extender) Sodium Nitrate Lime Caustic Soda Soda Ash/Sodium Bicarbonate Lost Circulation Material Total 3.) Percent by Weight 80-90 3-4 12-24 0-5.2 0-2 0-0.7 0-0.1 0-1.1 0-0.5 0-0.02 0-5 0-1.1 0-0.5 0-2.5 100.0 Pounds Pounds per Barrel per Gallon 350 8.33 12-18 0.30-0.40 45-100 1.07-2.38 11-22 0.26-0.52 0-8 0-0.2 0-3 0-0.07 0-0.5 0-0.01 0-5 0-0.11 0-2.0 0-0.05 0-0.1 0-0.002 0-20.0 0-0.5 0-5.0 0-0.11 0-2.0 0-0.05 0-10.5 0-0.25 420-504 10.0-12.0 Completion fluid: Normally a 3% KCl and saturated NaCl brine with the following properties (undiluted 10.0 ppg, diluted 2 to 1 - 8.9 ppg): -21- /-"\ ,.,/", Percent Pounds Pounds by Weight per Barrel per Gallon 83.3 350 8.33 3.0 12 0.30 13.3 57 1.35 0.4 1 0.02 100.0 420 10.00 Material Fresh Water Potassium Chloride (KCn Sodium Chloride (NaCl) XC Polymer Total The drilling/completion fluids proposed for injection are not defined as hazardous by the Resource Conservation and Recovery Act (Re: 40 CFR 261.4(b)(5». The drilling mud described is essentially similar to Generic Mud No.1 as identified by EP A and approved for offshore discharge under the auspices of a National Pollution Discharge Elimination System (NPDES) permit. Estimated amounts to be injected daily The average water injection rate for the Swanson River Field is dependent on the daily produced water production. The daily average for May 1986 was 6000 BWPD. The maximum injection rate is limited by the water injection pumps and wellhead pressure, at this time the maximum estimated injection rate is 18,000 BWPD. Compatibility with formation and confining zones - The vast majority of injected fluid is produced waters which are compatible with the injection formation. -22- ClIEAllCAL & r~OLOGICAL LABORATORIP-~\OF ALASKA, INC, ... Complny Well No, Field TELEPHONE (9071 562-2343 ANCHORAGE INDUSiRIAL CENTER 5633 B Strttt FEBmARi 28, 1986 GAS ANALYSIS REPORT 01èvr0n, , U.S.A. Date location 2-27-86 pit- l.8b No. 2142-2 II Formation ~~ ~~ Stat. Sa~pJjn9 Point Field 900 ~ 'I<ll & Kl~ 2-18~86 line p~essure - psig; Sample ~ressur.108~8jg; Temperature 56 Remarks '- '- 8F; Container number - - - - , , . Component Mole" Volume 0.0085 OICygeo......... ................. ..'.......... ...... ..... :".""'" Nitrogen.. ............ ............... ....... ........ ............. 1.5112 Carbondioxid....................................,..............0,,0615 Hydrogen sulfide ...... .... ........ ... ........ ........... ....... .,.................~...................... 93.5689 Methane ..... ..'" ... .......... ""'oo."""""'" ...... ....... . Ethane .....................,.................................... 1.9615 Propane ....... ....... ,.., .......... ...... """"""""""'" 1. '9AQ Iso.butane . . . .. ""oo . oo .. . . . . . . . . . . .. .. ... . . , , ....... . ... .... . . ... 0.3153 , . .' ;. N.butan8 ............... ......................................... 0_.,4294 0.0983 0.0910 0.1057 H,.ln..... ...... ....... ...... ....... ,.. ,........ ........ ..... ... 0.0499 Heptanes & HIgher............................................... " - ......................-...................L. I , . . , Iso.pentane.. . . . .. . ... . . . . . . . . . . .. . . . . . ~ . . . ~ . .:. ,'ò"", . .. .. .. .. . I N.pen..n..... ................ ....... ....... ... .............. .... ,~ 100.0000 .Totll~..:.:::.'.:..... . .. ~' Grossbtu eu.ft.@60'F. & '4.1p5ia(drybuis).....;...............' Specific gravity (calculated from analysis). . . ... .. . ....... ... .. .. .... Of Specific gravity (measured) . . .. .... . . .. , ... .... . .... .. ..,.... .. . ..... Remarks: -23- or " -------- - '.. \0. " . '\, 1064.35 " \ '.., ' 0.6061 .... \ Attachment 3-1 Gas Analysis Report /~~ --- " " CHEMICAL & GEOLOGICAL LABORA TORIES OF ALASKA, INC. P.O. BOX 4.1276 Anchorage. Alaska 99509 TELEPHONE (907) 562.2343 ANCHORAGE INDUSTRIAL CENTER 5633 B Street OPERATOR WELL NO. FIELD COUNTY STATE Chevron, U. S. A. WATER ANAL YSISREPORT 1 3, 1984 LAB NO. Alaska REMARKS & CONCLUSIONS: Cations Sodium. . . . . . . . . . . . . Potassium........... Calcium .. . . . . . . . . . . . Magnesium.......... Iron. . ......... "'" mg/1 4700 30 5231) 40 Total Cations ......... DATE November LOCATION FORMATION INTERVAL SAMPLE FROM 1-33 ww Discharge Suspended Solids, mg!1----------102 Barium (Ba). mq/l--------------- 16 Strontium (Sr). mQ!1------------ 94 Iron (Fe). mq!l----------------- 6.4 meg/1 204.44 0.77 260.98 3.29 469.48 Total dissolved solids, mg/1 . . . . . . . . . . 26591 NaC1 equivalent, mg/1 """"""" 26192 Observed pH..;.................... 5.1 Anions Sulfate.............. Chloride............. Carbonate........... Bicarbonate. . . . . . . . . Hydroxide........... mg/1 32 16200 0 730 0 TotaIAnions.......... Specific resistance @ 68° F.: Observed ..,....... Calculated """'" 0.29 0.28 WATER ANALYSIS PATTERN Scale MEa per Unit Sample above described : !,I ;'/: Ii ):1:: I!! j I 1/: i ! li,lil)! i:i; I' II :' ""","'11""""1 II' ¡ :1 i: ill II' ¡: , I' ::¡ :; I: Iii : ; I ¡: ~: I: ¡ , ! ¡ ! i I ¡ ¡: I:: ii, i Na ;\:¡\¡¡¡:!!U!Î!;¡¡¡:! i ¡¡!~í!!!¡ C1 I " '" I ¡ 'I I : I, ¡; , j ì I ,I : : II II j ~ :: I: 11 ¡; I I'!!! II': II .1: I' I ! I j! ìïl! il Ca .¡", I'¡II' 'I"'III"I" HCO' , '"I::: I,', ': ' ':, ,i : 'I' '! ,II '!, I 'I :1; II': ,I: II" ,I: , :: ,::, ::1 ill " I , " , I I " , ' " " , ," I """'1""1'1"1"1"11"1,,,,,11 il': :::, ,,: .:' : , '! I; ; i ' ,; I' '" Mg",'I"'I,¡",!!""",:I,,¡, ,',,' SO' :, i :!:, II: i:: I; 'I ) " i: : : ì I::, :, I: ; I ," "" I", "II ' I "" , " "" 'I I ",I "I' III", "", I " ,"I I' 'I " \ ¡: i : ¡! ¡ ; i ¡ ¡ 1: ¡ ¡ ¡;!!; ¡ j ::; ¡ !:' ¡ ¡ i; ¡: ¡ Fe lil'III,'I,'>:¡:!:III'il'ii¡:I;¡>¡i;I'"ii';!1 CO' : : i, I", : 11: I ,/ i I :; ':,: i:' I I ¡ ! ' :!!: I ' : 'i ::;: ;;:; j' I'" i ::;, 'i II :!, i", : I; :',,:,::¡ ~:;!:-:"::,,:!:;,;I::lil\ . 200' "i\I::: :' 1\ 11' I' ¡Ii I), I :; : 'I': "I: II I " , ' I I .\' '" " I' I, "II II" II : I : i : : ; ,; II, :: I, ' : i": :::, ;: I : , { I ¡ iiii ¡ I¡ ¡;I ')i i I! i:¡: 'I! I Na II! I:.': I :¡ ¡'I: ;; I II. ¡:11 II Ii C1 \ i "1; , ¡I:: Ii': :::: 'I 'I I ::' " I ; ; :' I , ' '" ,:: ' I,: : I I II I 'j:. i" ¡ :,:11! II: Caliil'I'I'I'I¡I"'IIII"'1 II a ""I,:j'II:",,:,::::,:, I HCO i:;! ,'!I :i I ' : 1;1 :::!. i!:1 :;; 'I' I , I " II" " " ,I III I!'" I:!, ,I! ' I I ¡ ¡ ! I ,: I : i ¡ I : ': ¡ i ¡ : :: : ¡ I: :: ~ I :! d I '", ,I, "', ,,1'1'" ,I I" ,," "" I Mg :il;;¡i:::i"¡,¡::¡;:'::¡'::::!¡ijl;; SO' 'j'" "'.""" 1""'.'1"111 :,: ¡ : i:: ,':, I !j ;i:: ','" I ::¡, I :dill;i:lill¡!!ij!! ::¡¡:~;I¡!¡:¡¡III Fe ;:I'I"¡jl'I~I;:'I:::'::'I'I:""';jl',1:1'11 CO' , I' II ' I' I" .", I I " "" , : : I '!,: I Ii; I. . I:' ,'; ,.'1: ; ': ; , : í ',," , ,! ! : .' I,: :. I " " I '. ; ¡ i I ; : '! I;: :' I!; ¡ i ' ~: :: ' :. !: ¡: ¡I, 20 20 20 -24- INI ..1... I.. abo.. lI,aphl I"cl..dn HI. K. .n4 L1) NOTE.: 1.1;11 . MiII;;'.",a pe' Ii'.' M4tq/1 . Milligram .q..iu,."t per nlef Sodi..", Chlorid. eq..i..I."t . by O.."..p & H..,tho",. c.lc..lalio" Irom co"'p... 7067 meg/1 0:-67 456.84 11.97 469.48 ohm.meters ohm.meters Attachment J-2 Water Analysis Report /.i".., SECTION K Injection Pressure 20 AAC 25.402(c)(10) 20 AAC 25.252(c)(8) Gas Injection (EOR) Well Injection Pressure The current average injection pressure is 5180 psi with a range of 4800 to 5800 psi. The maximum injection pressure is limited by the compressor plant maximum output pressure, which is 6300 psi. Fluid Disposal Well The current average water injection pressure is 815 psi. This can range from 700-850 psi depending on injection rate. The maximum injection pressure obtainable is 1400 psi, the maximum output pressure of the water injection pumps at low rates. Injection pressure is limited to 1000 psi by existing EP A DIC permits. -25- /-"", ,.---" SECTION L Fracture Information 20 AAC 25.402(c)(1l) 20 AAC 25.252(c)(9) The proposed maximum injection pressures for the enhanced recovery and fluid disposal wells will not initiate fractures in the confining strata which might enable the injection or formation fluid to enter freshwater strata. Subsection 1 Enhanced Recovery Injection in the Hemlock Formation occurs at pressures which would not breach the integrity of the confining zone. Confining mudstones and siltstones directly above the Hemlock range in thickness from 20-40 ft. Some portions of the field have a small sand lobe adjacent to the Hemlock, called the G Sand, which is then overlain by thousands of feet of impermeable Tyonek siltstones and mudstones. Any fractures which may occur in the injection zone (Hemlock Formation) would be confined to that zone and would not significantly penetrate the confining layers. Subsection 2 Fluid Disposal Injection pressures in the fluid disposal wells will also be maintained below parting pressures. The fracture pressure required to initiate a fracture in the injection or confining zone is dependent on the rock properties of the formation and the fluid properties of the injection fluid. For the wells in question, the water disposal wells, we believe that the current injection pressures are not fracturing the injection zone or any of the confining zones. Even if the immediate confining zone failed, there are several confining zones between the injection interval and 1700'. Refer to the SRU 32-33 Dual Induction Electric log which shows the injection and confining zones (Attachment G-2). -26- /~, /-\ To determine the pressure required to create a fracture in the injection or confining zone, the following equation can be used: (POv = ~ a; +Sh+Pr - ".., .... Assume ~ = Ct,= au. (1) Where (pi)v = Vertical Fracture Initiation Pressure (psi) I"\- cr¡ = Eff. Horizontal Compressive Strength (psi) Pr = Reservoir Pressure (psi) Sh = Rock Tensile Strength (psi) The reservoir pressure is assumed to be 910 psi, which is a normal water gradient (.433 psi/ft) at a typical injection depth of 2100'. The tensile strength of the rock can vary from 120-500 psi, for sandstones. The effective horizontal compressive strengths must be calculated using the following equation: ..... o¡= -y toy (.007 D-Pr) (2) Where '"Y' = Poisson's Ratio D P = Depth of Injection = Density of the Formation The reservoir pressure and depth of injection have already been mentioned, the Poisson's ratio for reservoir rocks varies from .15 - .40, and the density of the formation is 144 Ib/cu.ft. (sandstone density). Using the possible ranges of the rock property data the vertical fracture initiation pressure can vary from 1456 psi to 3020 psi. The corresponding sur (ace pressures for these pressures are 547 psi to 2111 psi using the following equation: (pi)s = (pi)v - .433SgD (3) Where (Pi}s= Surface Pressure to initiate a fracture (psi) Sg = Specific gravity of injection fluid (Water = 1.00) This calculated fracture pressure assumes that none of the injection fluid enters the pore spaces in the injection formation. Since the injection formation has permeability (this is known because these sands are productive in other portions of the field) and the -27- ; '"'"'" ~ fluid does enter the pores of the formation. To determine how much fluid the formation can take,Darcy's radial flow equation, is used: Q = 7.082kh (Pr-Pw)/wln (re-rw) (4) Where Q = Flowrate (BPD) k = Permeability (Darcy's) h = Formation Thickness (ft) Pw = Bottomhole (Production/injection) pressure (psi) w = Fluid viscosity (cp) re = Drainage radius (ft) rw = Wellbore radius (ft) Using an average permeability of .01 Darcy's (10 md), formation thickness of 280 ft, water viscosity of .37cp, drainage radius of 1000 ft (approx. 80 acre spacing), wellbore radius of .411 ft (for 9 7/8" hole), and the current average injection pressure of 1710 psi (for a surface pressure of 800 psi) the flowrate that the injection zone can handle is :6,200 BPD. This indicates that the formation is taking all the injection fluid in which case the formation is not being fractured. The values used in calculating this flowrate are typical for this area and it is possible that they may be different than those shown, however we believe that they are a reasonable estimate and that the injection and confining zones are not being fractured. -28- ~'. SECTION M Formation Fluid 20 AAC 25.402(c)(12) 20 AAC 25.252(c)(10) ~~ A water analysis for the Hemlock Formation is included as Attachment J-2. -29- RECEIVED fEB - 9 1987 Alaska Oil & Gas Cons. Commission Anchorage ,~, .~ SECTION N Aquifer Exemption 20 AAC 25.402(c)(13) 20 AAC 25.252(c)(ll) The injection of water and gas in the Swanson River Field is all below a depth of 1700 feet. As per 40 CFR 147.102(b) the aquifers in the Swanson River Field are exempted in accordance with 40 CFR 144.7(b) and 40 CFR 146.4. -30- ,~ .?""_, SECTION 0 Hydrocarbon Recovery 20 AAC 25.402(c)(14) Total expected hydrocarbon recovery from the SRU is 212 MMSTB billion barrels of oil, or 49% of currently estimated oil originally in place. Without pressure maintenance by gas injection, recovery would be less than 10%. -31- /~ /-" , SECTION P Mechanical Integrity 20 AAC 25.402(d) and (e) 20 AAC 25.252(d) and (e) In newly drilled wells, the casing is pressure tested in accordance with 20 AAC 25.030(g) (see also Attachment 1-1). If converted to injection, the casing is again pressure tested in accordance with 20 AAC 25.412(c). The casing annulus pressure is then monitored on a daily basis and recorded by the drill site operator. RECEIVED fEB - 9 1987 Alaska Oil & Gas Cons. Commission Anchorage -32- ... /---. '-' SECTION Q Wells Within Area 20 AAC 25.402(h) 20 AAC 25.252(h) The wells within the area of review (i.e., SRF)are shown on the plat (Attachment B-1). To the best of ARCO Alaska, Inc.'s knowledge, the wells within the area were constructed, and where applicable, abandoned to prevent the movement of fluids into freshwater sources. " -33-