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Home My WebLink AboutSIO 003• • INDEX STORAGE INJECTION ORDER NO. 3 1. March 6, 2002 2. March 22, 2002 3. March 25, 2002 4. Apri129, 2002 5. April 30, 2002 6. April 30, 2002 7. ----------------- 8. Apri130, 2002 9. Apri130, 2002 10. June 6, 2002 11. April 14, 2003 12. September 27, 2004 13. February 23, 2009 Unocal Application for Injection Order for Gas Storage KGSF #2, Swanson River Field with attachments Notice of Public Hearing, Affidavit of Publication, Copy of bulk mailing List Unocal's Revision to the Application Questions to Unocal Various Documents submitted by Operator to AOGCC Sign In Sheet Questions/Concerns/Comments to Unocal from AOGCC Map Transcript Correspondence from Unocal to Agency Notice of Public Hearing, Affidavit of Publication, Copy of bulk mailing List, Unocal Request for an Administrative Approval and ultimately the Commission's Denial of request. Proposals to amend underground injection orders to incorporate consistent language addressing the mechanical integrity of wells. Chevron's report re: annual material balance calculations of production and injection volumes for Tyonek 77-3 sand for 2009 STORAGE INJECTION ORDER NO 3 ,.--., ~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue Anchorage, Alaska 99501 Re: THE APPLICATION OF UNION OIL COMPANY OF CALIFORNIA ("Unocal") for an order authorizing the underground storage of hydrocarbons by injection into the Tyonek Formation in proposed well Swanson River Unit KGSF #2. ) Storage Injection Order No.3 ) ) Swanson River Field ) Swanson River Unit Well KGSF #2, ) (Re-drill of SRU #12-27) ) ) June 19, 2002 IT APPEARING THAT: 1. By application dated March 6, 2002 and received by the Alaska Oil and Gas Conservation Commission ("Commission") on March 7, 2002, Union Oil Company of California ("Unocal") requested an order from the Commission authorizing the underground storage of hydrocarbons by injection into the Tyonek Formation of the proposed Swanson River Unit ("SRU") KGSF #2 well. This proposed well is a 500-foot long, lateral re-drill of existing well SRU #212-27, which is located in Section 27, Township 8 North, Range 9 West, Seward Meridian. 2. Unocal proposes to inject gas into SRU KGSF #2 for storage during summer months and produce back the gas for sales during winter months to meet peak demand. 3. Notice of opportunity for public hearing was published in the Anchorage Daily News Anchorage Daily News on March 22, 2002 in accordance with 20 AAC 25.540. 4. By letter dated March 25, 2002 and received by the Commission on March 28, 2002, Unocal requested well SRU KGSF #2 be a re-drill of existing well SRU #12- 27 instead of well SRU #212-27. 5. The Commission received no comments concerning the application or requests for a public hearing. 6. By Commission request, a hearing concerning Unocal's application was convened in conformance with 20 AAC 25.540 at the Commission's offices, 333 W. 7th Avenue, Suite 100, Anchorage, Alaska 99501 on April 30, 2002. .""" ,.-, Storage Injection Order 1. -. 3 June 19,2002 Page 2 FINDINGS: 1. Unocal is the operator of the Swanson River Field. 2. Unocal proposes to drill a 500-foot lateral extension to the existing well SRU #12- 27, rename the well SRU KGSF #2, and utilize the lateral extension for the proposed storage injection program. 3. The gas storage project is intended to provide a certain stored volume of gas to meet peak rate requirements during seasonal high demand periods. The design is intended to put a large volume into a reservoir at relatively high injection rate and withdraw the gas at a relatively high rate during peak demand periods. 4. Well SRU #12-27 and Unocal's proposed lateral extension lie within Federal lease A-028406. The U.S. Department of the Interior is the owner of the subsurface rights. 5. There are no other operators within a one-quarter mile radius of the proposed SRU KGSF #2 well. 6. Unocal has given notice of its application by certified mail to the surface owners within a one-quarter mile radius of the proposed SRU KGSF #2 well. 7. 40 CFR l47.102(b) provides that aquifers below 1700 feet from the surface and within a Y4 mile of the Swanson River Field are exempted in accordance with 40 CFR l44.7(b) and 40 CFR 146.4. 8. Unocal proposes to conduct dry gas storage injection within the proposed SRU KGSF #2 well in the 62-5 sand of the Tyonek Formation. Unocal describes this sand as lying between 6233 and 6253 feet MD in offset well SRU #212-27. 9. Two other wells lie within one-quarter mile radius of the proposed SRU KGSF #2 well: SRU #212-27 and SRU #314-27. These wells penetrate the 62-5 sand in the proposed gas storage area. Offset well SRU #21-27 lies slightly more than Y4 mile northeast of KG SF #2, and it also penetrates the 62-5 sand. 10. Upper confinement of the 62-5 gas sand is provided by 13 feet of impermeable claystone, which is overlain by 10 feet of coal, and then approximately 50 feet of water-bearing sandstone. Lower confinement is provided by about 19 feet of impermeable siltstone and claystone that is underlain by 21 feet of water-bearing sandstone. 11. Calculated porosity for the 62-5 sand ranges from 24 to 30 percent. Average water saturation is estimated to be between 45 and 55 percent. Well SRU #212-27 was drilled from the same pad as SRU #12-27, and its surface location lies 211 feet to the southeast. At the top of the 62-5 sand, the well bores are approximately 260 feet apart. During September of 1997, the 62-5 sand was perforated in SRU #212- 27 from 6237 feet to 6254 feet MD, and put on gas production. By February of 2001, the 62-5 interval no longer flowed gas, and it was abandoned. ,"'"" Storage Injection Order j:,.-. 3 June 19,2002 ~ Page 3 12. Initial reservoir pressure in SRU #212-27 was 2841 psia at 6078' TVDss (Application dated March 6, 2002 - Attachment 6). This is equivalent to 2852 psia at 6245' MD and TVDss in the SRU #212-27 well. 13. Reservoir pressure was depleted to about 800 psi after producing 2 BCF based on the material balance P/Z versus cumulative plot presented in the application. 14. Material balance analysis of historical production and injection indicate an original gas in place of 2.9 BCF in the 62-5 sand. Produced volume corresponds to 69% recovery as of May 2001. Material balance analysis supports the contention that the interval proposed for gas storage covers a limited area and is isolated from other strata. 15. Well records indicate the 62-5 sand in the SRU #12-27 and #212-27 wells is adequately protected by casing and cement. Perforations in the 62-5 sand within the SRU #212-27 well have been properly abandoned. 16. Well records indicate the 62-5 sand in well SRU #21-27 is covered by 7 inch production casing, but is not protected by cement. Unocal interprets the 62-5 sand in SRU #21-27 as being separated by a permeability barrier from the 62-5 sand of the proposed injection area that surrounds SRU #12-27. 17. The operator will monitor offset wells and storage well operating parameters to ensure gas does not move out of the storage sand. 18. The fluid proposed for injection is predominantly dry methane produced from a liquid extraction plant for produced gas from the Hemlock Formation in the Swanson River Field and from the Trading Bay Unit. Specific gravity of the injected gas is expected to be 0.59 (air = 1.0). 19. Estimated maximum daily injection volume is 10 MMSCF/D, and expected average wellhead injection pressure is 2700 psi. Proposed maximum injection pressures will be maintained less than compressor outlet pressure of 3000 psi, 20. Formation fracture gradients measured in shallower and deeper formations ranged from .8 psi to 1.03 psi per foot. The Tyonek Formation did not have any direct fracture gradient determined. Calculated fracture gradient for sandstones with 25 percent porosity and gas saturation range from .6 to 1.0 psi/foot at the depth of the Tyonek 62-5 sand. 21. If the maximum injection pressure is limited to a wellhead pressure of 3000 psi, fractures will not be propagated in the sandstone or confining strata. This limitation is equivalent to a pressure gradient of .54 psi/foot to the Tyonek Formation 62-5 sand at 6245 TVDss. 22. The Operator will demonstrate the mechanical integrity of SRU KGSF #2 according to the provisions of 20 AAC 25.252( d) prior to initiating gas injection and storage operations. ..""" -, Storage Injection Order 1, . 3 June 19,2002 Page 4 CONCLUSIONS: 1. The project as described and proposed meets the requirements of 20 AAC 25.252. 2. The proposed injection of natural gas into the SRU KGSF #2 well for the purpose of storage will not cause movement of hydrocarbons into sources of freshwater. 3. The proposed storage of natural gas in SRU KGSF #2 will not cause fluids to move behind casing beyond the approved storage zone. 4. The proposed storage of natural gas in well SRU KGSF #2 will not propagate fractures through the confining zones. 5. The proposed injection of natural gas into the SRU KGSF #2 well for the purpose of storage will not cause waste, jeopardize correlative rights, endanger freshwater, or impair ultimate recovery. 6. Surveillance of operating parameters on the storage well and offset wells will aid in preventing stored gas from moving out of the formation where it is intended to be stored. NOW, THEREFORE, IT IS ORDERED THAT: RULE 1: Storaee Injection Injection of natural gas for storage is authorized into the 62-5 sand of the Tyonek Formation; correlative to the 62-5 sand between 6233 - 6253 feet MD in SRU #212-27, within the SRU KGSF #2 well bore. RULE 2: Maximum Injection Pressure The maximum wellhead injection pressure shall be limited to 3000 psi or a formation pressure gradient of .54 psi per foot. RULE 3: Monitorine Proeram Operating parameters including injection rate, injection pressure, and annulus pressures (for both the injection well and offsets within 1/2 mile) must be monitored and reported to the Commission on a monthly basis. An annual report evaluating the performance of the injection operation must be submitted in conjunction with the annual material balance calculations described below. ,~ .~, Storage Injection Order l\~. 3 June 19,2002 Page 5 RULE 4: Annual Material Balance The operator shall provide an annual material balance calculation of the gas production and injection volumes to provide assurance of continued reservoir confinement of the gas storage volumes. This information shall be submitted no later than 60 days after the beginning of each calendar year. RULE 5: Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive the requirements of any rule stated above or administratively amend any rule as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in an increased risk of fluid movement into freshwater. RULE 6: Other Conditions Operations must be conducted in accordance with AS 31.05 and Title 20 Chapter 25 of the Alaska Administrative Code unless specifically superseded by Commission order. Failure to comply with an applicable provision of AS 31.05, Title 20 Chapter 25 of the Alaska Administrative Code or a Commission order may result in the revocation or suspension of this authorization. DONE at Anchorage, Alaska and dated June 19,2002. &~. (1~lvyl '~~W Cammy 0 chsli Taylor, ~air. ~;;:miSSion Daniel T. Seamount,/k, Commissioner Alaska Oil and Gas Conservation Commission AS 31,05,080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can retùse an application by not acting on it within the 1O-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 3O-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). /'""'. ~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th A venue Anchorage, Alaska 99501 Re: THE APPLICATION OF UNION OIL COMPANY OF CALIFORNIA (tlUnocaltl) for an order authorizing the underground storage of hydrocarbons by injection into the Tyonek Formation in proposed well Swanson River Unit KGSF #2. ) Storage Injection Order No.3 ) ) Swanson River Field ) Swanson River Unit Well KGSF #2, ) (Re-drill of SRU #12-27) ) ) June 19, 2002 IT APPEARING THAT: 1. By application dated March 6, 2002 and received by the Alaska Oil and Gas Conservation Commission ("Commission") on March 7, 2002, Union Oil Company of California ("Unocal") requested an order from the Commission authorizing the underground storage of hydrocarbons by injection into the Tyonek Fonnation ofthe proposed Swanson River Unit ("SRU") KGSF #2 well. This proposed well is a 500-foot long, lateral re-drill of existing well SRU #212-27, which is located in Section 27, Township 8 North, Range 9 West, Seward Meridian. 2. Unocal proposes to inject gas into SRU KGSF #2 for storage during summer months and produce back the gas for sales during winter months to meet peak demand. 3. Notice of opportunity for public hearing was published in the Anchorage Daily News Anchorage Daily News on March 22, 2002 in accordance with 20 AAC 25.540. 4. By letter dated March 25, 2002 and received by the Commission on March 28, 2002, Unocal requested well SRU KGSF #2 be a re-drill of existing well SRU #12- 27 instead of well SRU #212-27. 5. The Commission received no comments concerning the application or requests for a public hearing. 6. By Commission request, a hearing concerning Unocal's application was convened in confonnance with 20 AAC 25.540 at the Commission's offices, 333 W. 7th Avenue, Suite 100, Anchorage, Alaska 99501 on April 30, 2002. /""'. ~ Storage Injection Order No.3 June 19,2002 Page 2 FINDINGS: 1. Unocal is the operator of the Swanson River Field. 2. Unocal proposes to drill a 500-foot lateral extension to the existing well SRU #12- 27, rename the well SRU KGSF #2, and utilize the lateral extension for the proposed storage injection program. 3. The gas storage project is intended to provide a cenain stored volume of gas to meet peak rate requirements during seasonal high demand periods. The design is intended to put a large volume into a reservoir at relatively high injection rate and withdraw the gas at a relatively high rate during peak demand periods. 4. Well SRU #12-27 and Unocal's proposed lateral extension lie within Federal lease A-028406. The U.S. Department of the Interior is the owner of the subsurface rights. 5. There are no other operators within a one-quarter mile radius of the proposed SRU KGSF #2 well. 6. Unocal has given notice of its application by certified mail to the surface owners within a one-quarter mile radius of the proposed SRU KGSF #2 well. 7. 40 CFR 147.1 02(b) provides that aquifers below 1700 feet from the surface and within a ~ mile of the Swanson River Field are exempted in accordance with 40 CFR 144.7(b) and 40 CFR 146.4. 8. Unocal proposes to conduct dry gas storage injection within the proposed SRU KGSF #2 well in the 62-5 sand of the Tyonek Formation. Unocal describes this sand as lying between 6233 and 6253 feet MD in offset well SRU #212-27. 9. Two other wells lie within one-quarter mile radius of the proposed SRU KG SF #2 well: SRU #212-27 and SRU #314-27. These wells penetrate the 62-5 sand in the proposed gas storage area. Offset well SRU #21-27 lies slightly more than ~ mile northeast of KG SF #2, and it also penetrates the 62-5 sand. 10. Upper confinement of the 62-5 gas sand is provided by 13 feet of impermeable claystone, which is overlain by 10 feet of coal, and then approximately 50 feet of water-bearing sandstone. Lower confinement is provided by about 19 feet of impenneable siltstone and claystone that is underlain by 21 feet of water-bearing sandstone. 11. Calculated porosity for the 62-5 sand ranges from 24 to 30 percent. Average water saturation is estimated to be between 45 and 55 percent. Well SRU #212-27 was drilled from the same pad as SRU #12-27, and its surface location lies 211 feet to the southeast. At the top of the 62-5 sand, the well bores are approximately 260 feet apart. During September of 1997, the 62-5 sand was perforated in SRU #212- 27 from 6237 feet to 62.54 feet MD, and put on gas production. By February of 2001, the 62-5 interval no longer flowed gas, and it was abandoned. ~ ~ Storage Injection Order No.3 June 19,2002 Page 3 12. Initial reservoir pressure in SRU #212-27 was 2841 psia at 6078' TVDss (Application dated March 6, 2002 - Attachment 6). This is equivalent to 2852 psia at 6245' MD and TVDss in the SRU #212-27 well. 13. Reservoir pressure was depleted to about 800 psi after producing 2 BCF based on the material balance P /2 versus cumulative plot presented in the application. 14. Material balance analysis of historical production and injection indicate an original gas in place of 2.9 BCF in the 62-5 sand. Produced volume corresponds to 69% recovery as of May 2001. Material balance analysis supports the contention that the interval proposed for gas storage covers a limited area and is isolated from other strata. 15. Well records indicate the 62-5 sand in the SRU #12-27 and #212-27 wells is adequately protected by casing and cement. Perforations in the 62-5 sand within the SRU #212-27 well have been properly abandoned. 16. Well records indicate the 62-5 sand in well SRU #21-27 is covered by 7 inch production casing, but is not protected by cement. Unocal interprets the 62-5 sand in SRU #21-27 as being separated by a permeability barrier from the 62-5 sand of the proposed injection area that surrounds SRU #12-27. 17. The operator will monitor offset wells and storage well operating parameters to ensure gas does not move out of the storage sand. 18. The fluid proposed for injection is predominantly dry methane produced from a liquid extraction plant for produced gas from the Hemlock Formation in the Swanson River Field and from the Trading Bay Unit. Specific gravity of the injected gas is expected to be 0.59 (air = 1.0). 19. Estimated maximum daily injection volume is 10 MMSCF/D, and expected average wellhead injection pressure is 2700 psi. Proposed maximum injection pressures will be maintained less than compressor outlet pressure of 3000 psi. 20. Formation fracture gradients measured in shallower and deeper formations ranged from .8 psi to 1.03 psi per foot. The Tyonek Formation did not have any direct fracture gradient determined. Calculated fracture gradient for sandstones with 25 percent porosity and gas saturation range from .6 to 1.0 psi/foot at the depth of the Tyonek 62-5 sand. 21. If the maximum injection pressure is limited to a wellhead pressure of 3000 psi, fractures will not be propagated in the sandstone or confining strata. This limitation is equivalent to a pressure gradient of .54 psi/foot to the Tyonek Fonnation 62-5 sand at 6245 TVDss. 22. The Operator will demonstrate the mechanical integrity of SRU KGSF #2 according to the provisions of 20 AAC 25.252(d) prior to initiating gas injection and storage operations. ~ /""'--, Storage Injection Order No.3 June 19,2002 Page 4 CONCLUSIONS: 1. The project as described and proposed meets the requirements of 20 AAC 25.252. 2. The proposed injection of natural gas into the SRU KGSF #2 well for the purpose of storage will not cause movement of hydrocarbons into sources of freshwater. 3. The proposed storage of natural gas in SRU KGSF #2 will not cause fluids to move behind casing beyond the approved storage zone. 4. The proposed storage of natural gas in well SRU KGSF #2 will not propagate fractures through the confining zones. 5. The proposed injection of natural gas into the SRU KGSF #2 well for the purpose of storage will not cause waste, jeopardize correlative rights, endanger freshwater, or impair ultimate recovery. 6. Surveillance of operating parameters on the storage well and offset wells will aid in preventing stored gas from moving out of the formation where it is intended to be stored. NOW, THEREFORE, IT IS ORDERED THAT: RULE 1: Storaee Injection Injection of natural gas for storage is authorized into the 62-5 sand of the Tyonek Formation; correlative to the 62-5 sand between 6233 - 6253 feet MD in SRU #212-27, within the SRU KG SF #2 well bore. RULE 2: Maximum Injection Pressure The maximum wellhead injection pressure shall be limited to 3000 psi or a formation pressure gradient of .54 psi per foot. RULE 3: Monitorine Proeram Operating parameters including injection rate, injection pressure, and annulus pressures (for both the injection well and offsets within 1/2 mile) must be monitored and reported to the Commission on a monthly basis. An annual report evaluating the performance of the injection operation must be submitted in conjunction with the annual material balance calculations described below. /~ ~ Storage Injection Order No.3 June 19,2002 Page 5 RULE 4: Annual Material Balance The operator shall provide an annual material balance calculation of the gas production and injection volumes to provide assurance of continued reservoir confinement of the gas storage volumes. This information shall be submitted no later than 60 days after the beginning of each calendar year. RULE 5: Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive the requirements of any rule stated above or administratively amend any rule as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in an increased risk of fluid movement into freshwater. RULE 6: Other Conditions Operations must be conducted in accordance with AS 31.05 and Title 20 Chapter 25 of the Alaska Administrative Code unless specifically superseded by Commission order. Failure to comply with an applicable provision of AS 31.05, Title 20 Chapter 25 of the Alaska Administrative Code or a Commission order may result in the revocation or suspension of this authorization. DONE at Anchorage, Alaska and dated June 19,2002. &~. ()vj~ 'Jt;:-jW Cammy 0 chsli Taylor, If}-air ~jSSion Daniel T. Seamount,*., Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). I certify thai 00 - Le!!)¡D /(p., 8 -. of the above WS$ ~eci~iled to eecII T/ WI~!~~~~ of NY PUBLIC LIBRARY DIV E, GRAND CENTRAL STATION POBOX 2221 NEW YORK, NY 10163-2221 US MIN MGMT SERV, CHIEF OCS STATS & INFO 381 ELDEN ST MS 4022 HERNDON, VA 20170-4817 TECHSYS CORP, BRANDY KERNS PO BOX 8485 GATHERSBURG, MD 20898 SD DEPT OF ENV & NATRL RESOURCES, OIL & GAS PROGRAM 2050 W MAIN STE #1 RAPID CITY, SD 57702 LINDA HALL LIBRARY, SERIALS DEPT 5109 CHERRY ST KANSAS CITY, MO 64110-2498 10GCC, POBOX 53127 OKLAHOMA CITY, OK 73152-3127 BAPI RAJU 335 PINYON LN COPPELL, TX 75019 STANDARD AMERICAN OIL CO, AL GRIFFITH POBOX 370 GRANBURY, TX 76048 H J GRUY, ROBERT RASOR 333 CLAY STREET SUITE 3850 HOUSTON, TX 77002 CHEVRON, PAUL WALKER 1301 MCKINNEY RM 1750 HOUSTON, TX 77010 ~ OFFICE OF THE GOVERNOR, JOHN KATZ STE 518 444 N CAPITOL NW WASHINGTON, DC 20001 LIBRARY OF CONGRESS, STATE DOCUMENT SECTION EXCH & GIFT DIV 10 FIRST ST SE WASHINGTON, DC 20540 US GEOLOGICAL SURVEY, LIBRARY NATIONAL CTR MS 950 RESTON, VA 22092 BP EXPLORATION (ALASKA), INC., LlBRARYliNFO CTR POBOX 87703 CHICAGO, IL 60680-0703 ALFRED JAMES III 107 N MARKET STE 1000 WICHITA, KS 67202-1811 R E MCMILLEN CONSULT GEOL 202 E 16TH ST OWASSO, OK 74055-4905 US DEPT OF ENERGY, ENERGY INFORMATION ADMINISTRATION MIR YOUSUFUDDIN 1999 BRYAN STREET STE 1110 DALLAS, TX 75201-6801 XTO ENERGY, MARY JONES 810 HOUSTON ST STE 2000 FORT WORTH, TX 76102-6298 PURVIN & GERTZ INC, LIBRARY 2150 TEXAS COMMERCE TWR 600 TRAVIS ST HOUSTON, TX 77002-2979 OIL & GAS JOURNAL, BOB WILLIAMS 1700 W LOOP SOUTH STE 1000 HOUSTON, TX 77027 ~, ARENT FOX KINTNER PLOTKIN KAHN, LIBRARY WASHINGTON sa BLOG 1050 CONNECTICUT A V NW WASHINGTON, DC 20036-5339 US DEPT OF ENERGY, PHYLLIS MARTIN MS EI823 1000 INDEPENDENCE SW WASHINGTON, DC 20585 DPC, DANIEL DONKEL 2121 NORTH BAYSHORE DR #616 MIAMI, FL 33137 ILLINOIS STATE GEOL SURV, LIBRARY 469 NATURAL RESOURCES BLDG 615 E PEABODY DR CHAMPAIGN, IL 61820 UNIV OF ARKANSAS, SERIALS DEPT UNIV LIBRARIES FAYETTEVILLE, AR 72701 OIL & GAS JOURNAL, LAURA BELL POBOX 1260 TULSA, OK 74101 DEGOL YER & MACNAUGHTON, MIDCONTINENT DIVISION ONE ENERGY sa, STE 400 4925 GREENVILLE AVE DALLAS, TX 75206-4083 SHELL WESTERN E&P INC, G.S. NADY POBOX 576 HOUSTON, TX 77001-0574 RAY TYSON 2016 MAIN #1415 HOUSTON, TX 77002-8844 PETRAL CONSULTING CO, DANIEL L LIPPE 9800 RICHMOND STE 505 HOUSTON, TX 77042 AURORA GAS, G. SCOTT PFOFF 10333 RICHMOND AVENUE, STE 710 HOUSTON, TX 77042 MARK ALEXANDER 7502 ALCOMITA HOUSTON, TX 77083 EXXON EXPLOR CO, LANDIREGULATORY AFFAIRS RM 301 PO BOX 4778 HOUSTON, TX 77210-4778 PETR INFO, DAVID PHILLIPS POBOX 1702 HOUSTON, TX 77251-1702 EXXONMOBIL PRODUCTION COMPANY, J W KIKER ROOM 2086 POBOX 2180 HOUSTON, TX 77252-2180 MARATHON OIL COMPANY, NORMA L. CALVERT POBOX 3128, Ste 3915 HOUSTON, TX 77253-3128 TESORO PETR CORP, LOIS DOWNS 300 CONCORD PLAZA DRIVE SAN ANTONIO, TX 78216-6999 XTO ENERGY, DOUG SCHULTZE 3000 N GARFIELD SUITE 175 MIDLAND, TX 79705 DIANE SUCHOMEL 105070 W MAPLEWOOD DR LITTLETON, CO 80127 C & R INDUSTRIES, INC... KURT SAL TSGAVER 7500 W MISSISSIPPI AVE STE C4 LAKEWOOD, CO 80226-4541 ~. GAFFNEY, CLINE & ASSOC., INC., LIBRARY 1360 POST OAK BLVD., STE 2500 HOUSTON, TX 77056 UNOCAL, REVENUE ACCOUNTING POBOX 4531 HOUSTON, TX 77210-4531 TEXACO EXPLORATION & PRODUCTION INC, CORRY WOOLINGTON PO BOX 36366 HOUSTON, TX 77236 PHILLIPS PETROLEUM COMPANY, W ALLEN HUCKABAY PO BOX 1967 HOUSTON, TX 77251-1967 PENNZOIL E&P, WILL 0 MCCROCKLIN POBOX 2967 HOUSTON, TX 77252-2967 ACE PETROLEUM COMPANY, ANDREW C CLIFFORD PO BOX 79593 HOUSTON, TX 77279-9593 JIM WHITE 4614 BOHILL SAN ANTONIO, TX 78217 BABCOCK & BROWN ENERGY,INC., 350 INTERLOCKEN BLVD STE 290 BROOMFIELD, CO 80021 GEORGE G VAUGHT JR POBOX 13557 DENVER, CO 80201 JERRY HODGDEN GEOL 408 18TH ST GOLDEN, CO 80401 ~ MARATHON OIL COMPANY, WILLIAM R HOLTON, JR. 5555 SAN FELIPE STREET SUITE 2511 HOUSTON, TX 77056-2799 EXXON EXPLORATION CO., T E ALFORD PO BOX 4778 HOUSTON, TX 77210-4778 CHEVRON USA INC., ALASKA DIVISION ATTN: CORRY WOOLINGTON POBOX 1635 HOUSTON, TX 77251 WORLD OIL, DONNA WILLIAMS POBOX 2608 HOUSTON, TX 77252 CHEVRON CHEM CO, LIBRARY & INFO CTR POBOX 2100 HOUSTON, TX 77252-9987 WATTY STRICKLAND 2803 SANCTUARY CV KATY, TX 77450-8510 INTL OIL SCOUTS, MASON MAP SERV INC POBOX 338 AUSTIN, TX 78767 ROBERT G GRAVELY 7681 S KIT CARSON DR LITTLETON, CO 80122 US GEOLOGICAL SURVEY, LIBRARY BOX 25046 MS 914 DENVER, CO 80225-0046 NRG ASSOC, RICHARD NEHRING POBOX 1655 COLORADO SPRINGS, CO 1655 80901- RUBICON PETROLEUM, LLC, BRUCE I CLARDY SIX PINE ROAD COLORADO SPRINGS, CO 80906 US GEOLOGICAL SURVEY, LIBRARY 2255 N GEMINI DR FLAGSTAFF, AZ 86001-1698 ANTONIO MADRID POBOX 94625 PASADENA, CA 91109 SHIELDS LIBRARY, GOVT DOCS DEPT UNIV OF CALIF DAVIS, CA 95616 US EPA REGION 10, THOR CUTLER OW-137 1200 SIXTH AVE SEATTLE,WA 98101 TRUSTEES FOR ALASKA, 1026 W. 4th Ave, Ste 201 ANCHORAGE, AK 99501 FOREST OIL, JIM ARLINGTON 310 K STREET STE 700 ANCHORAGE, AK 99501 AURORA GAS, J. EDWARD JONES 1029 W 3RD AVE, STE 220 ANCHORAGE, AK 99501 DEPT OF REVENUE, OIL & GAS AUDIT DENISE HAWES 550 W 7TH AV STE 570 ANCHORAGE, AK 99501 PRESTON GATES ELLIS LLP, LIBRARY 420 L ST STE 400 ANCHORAGE, AK 99501-1937 /'""- , JOHN A LEVORSEN 200 N 3RD ST #1202 BOISE, ID 83702 MUNGER OIL INFOR SERV INC, POBOX 45738 LOS ANGELES, CA 90045-0738 ORO NEGRO, INC., 9321 MELVIN AVE NORTHRIDGE, CA 91324-2410 H L WANGENHEIM 5430 SAWMILL RD SP 11 PARADISE, CA 95969-5969 MARPLES BUSINESS NEWSLETTER, MICHAEL J PARKS 117 W MERCER ST STE 200 SEATTLE, WA 98119-3960 DUSTY RHODES 229 WHITNEY RD ANCHORAGE, AK 99501 DEPT OF ENVIRON CONSERVATION, DIV OF AIR & WATER QUALITY TOM CHAPPLE 555 CORDOVA STREET ANCHORAGE, AK 99501 DEPT OF REVENUE, CHUCK LOGSTON 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 STATE PIPELINE OFFICE, LIBRARY KATE MUNSON 411 W 4TH AVE, STE 2 ANCHORAGE, AK 99501 ALASKA DEPT OF LAW, ROBERT E MINTZ ASST ATTY GEN 1031 W 4TH AV STE 200 ANCHORAGE, AK 99501-1994 ~ PLAYER GAS CO., GARY PLAYER 1671 WEST 546 S CEDER CITY, UT 84720 BABSON & SHEPPARD, JOHN F BERGQUIST POBOX 8279 VIKING STN LONG BEACH, CA 90808-0279 US GEOLOGICAL SURVEY, KEN BIRD 345 MIDDLEFIELD RD MS 999 MENLO PARK, CA 94025 ECONOMIC INSIGHT INC, SAM VAN VACTOR POBOX 683 PORTLAND, OR 97207 DEPT OF REVENUE, DAN DICKINSON, DIRECTOR 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 DEPT OF REVENUE, BEVERLY MARQUART 550 W 7TH AV STE 570 ANCHORAGE, AK 99501 DEPT OF ENVIRON CONSERVATION, DIV OF ENVIRONMENTAL HEALTH JANICE ADAIR 555 CORDOVA STREET ANCHORAGE, AK 99501 FAIRWEATHER, DUANE VAAGEN 715 L STREET STE 7 ANCHORAGE, AK 99501 GUESS & RUDD, GEORGE LYLE 510 L ST, STE 700 ANCHORAGE, AK 99501 GAFO,GREENPEACE PAMELA MILLER 125 CHRISTENSEN DR. #2 ANCHORAGE, AK 99501-2101 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS TIM RYHERD 550 W 7th AVE STE 800 ANCHORAGE, AK 99501-3510 DEPT OF NATURAL RESOURCES, DIV OIL & GAS WILLIAM VAN DYKE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JULIE HOULE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 BRISTOL ENVIR AND ENG SERVICE, MIKE TORPY 2000 W. INT'L AIRPORT RD #C-1 ANCHORAGE, AK 99502-1116 YUKON PACIFIC CORP, 1400 W BENSON BLVD STE 525 ANCHORAGE, AK 99503 ALASKA OIL & GAS ASSOC, JUDY BRADY 121 W FIREWEED LN STE 207 ANCHORAGE, AK 99503-2035 ARLEN EHM GEOL CONSL TNT 2420 FOXHALL DR ANCHORAGE, AK 99504-3342 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC DICK FOLAND 6881 ABBOTT LOOP RD ANCHORAGE, AK 99507 ROSE RAGSDALE 3320 EAST 41ST AVENUE ANCHORAGE, AK 99508 UON ANCHORAGE, INST OF SOCIAL & ECON RESEARCH TERESA HULL 3211 PROVIDENCE DR ANCHORAGE, AK 99508 ,~, DEPT OF REVENUE, OIL & GAS AUDIT FRANK PARR 550 W 7TH AVE STE 570 ANCHORAGE, AK 99501-3540 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JIM STOUFFER 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 ALASKA JOURNAL OF COMMERCE, ED BENNETT 2000 INTL AIRPORT W #A10 ANCHORAGE, AK 99502 HDR ALASKA INC, MARK DALTON 2525 C ST STE 305 ANCHORAGE, AK 99503 N-I TUBULARS INC, 3301 C Street Ste 209 ANCHORAGE, AK 99503 ANADRI LL -SCHLUMBERGER, 3940 ARCTIC BLVD #300 ANCHORAGE, AK 99503-5711 JAMES E EASON 8611 LEEPER CIRCLE ANCHORAGE, AK 99504-4209 BUREAU OF LAND MANAGEMENT, GREG NOBLE 6881 ABBOTT LOOP ROAD ANCHORAGE, AK 99507 VECO ALASKA INC., CHUCK O'DONNELL 949 EAST 36TH AVENUE ANCHORAGE, AK 99508 US BLM AK DIST OFC, GEOLOGIST ARTHUR BANET 949 EAST 36TH AVE STE 308 ANCHORAGE, AK 99508 ~ DNR, DIV OF OIL & GAS JAMES B HAYNES NATURAL RESRCE MGR 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS BRUCE WEBB 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 AK JOURNAL OF COMMERCE, OIL & INDUSTRY NEWS ROSE RAGSDALE 2000 INTL AIRPORT RD W #A10 ANCHORAGE, AK 99502 BAKER OIL TOOLS, ALASKA AREA MGR 4710 BUS PK BLVD STE 36 ANCHORAGE, AK 99503 ANADARKO, MARK HANLEY 3201 C STREET STE 603 ANCHORAGE, AK 99503 FINK ENVIRONMENTAL CONSULTING, INC., THOMAS FINK, PHD 6359 COLGATE DR. ANCHORAGE, AK 99504-3305 AMERICNCANADIAN STRATIGRPH CO, RON BROCKWAY 4800 KUPREANOF ANCHORAGE, AK 99507 US BUREAU OF LAND MNGMNT. ANCHORAGE DIST OFC PETER J DITTON 6881 ABBOTT LOOP ROAD ANCHORAGE, AK 99507 TRADING BAY ENERGY CORP, PAUL CRAIG 5432 NORTHERN LIGHTS BLVD ANCHORAGE, AK 99508 THOMAS R MARSHALL JR 1569 BIRCHWOOD ST ANCHORAGE, AK 99508 US MIN MGMT SERV, RICHARD PRENTKI 949 E 36TH AV ANCHORAGE, AK 99508-4302 GORDONJ.SEVERSON 3201 WESTMAR CIR ANCHORAGE, AK 99508-4336 US MIN MGMT SERV, RESOURCE EVAL JIM SCHERR 949 E 36TH AV RM 603 ANCHORAGE, AK 99508-4363 USGS - ALASKA SECTION, LIBRARY 4200 UNIVERSITY DR ANCHORAGE, AK 99508-4667 PHILLIPS ALASKA INC., JOANN GRUBER ATO 712 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA INC., MARK MAJOR ATO 1968 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA INC., KUP CENTRAL WELLS ST TSTNG WELL ENG TECH NSK 69 POBOX 196105 ANCHORAGE, AK 99510-6105 ANCHORAGE DAILY NEWS, EDITORIAL PG EDTR MICHAEL CAREY POBOX 149001 ANCHORAGE, AK 99514 NORTHERN CONSULTING GROUP, ROBERT BRITCH, P.E. 2454 TELEQUANA DR. ANCHORAGE, AK 99517 ASRC, CONRAD BAGNE 301 ARCTIC SLOPE AV STE 300 ANCHORAGE, AK 99518 ~~ US MIN MGMT SERV, AK OCS REGIONAL DIR 949 E 36TH AV RM 110 ANCHORAGE, AK 99508-4302 US MIN MGMT SERV, FRANK MILLER 949 E 36TH AV STE 603 ANCHORAGE, AK 99508-4363 US MIN MGMT SERV, LIBRARY 949 E 36TH AV RM 603 ANCHORAGE, AK 99508-4363 CIRI, LAND DEPT POBOX 93330 ANCHORAGE, AK 99509-3330 PHILLIPS ALASKA INC., LEGAL DEPT MARK P WORCESTER POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA INC., LAND DEPT JAMES WINEGARNER POBOX 10036 ANCHORAGE, AK 99510-0360 AL YESKA PIPELINE SERV CO, PERRY A MARKLEY 1835 S BRAGAW - MS 575 ANCHORAGE, AK 99512 DAVID W. JOHNSTON 320 MARINER DR. ANCHORAGE, AK 99515 GERALD GANOPOLE CONSULT GEOL 2536 ARLINGTON ANCHORAGE, AK 99517-1303 ARMAND SPIELMAN 651 HILANDER CIRCLE ANCHORAGE, AK 99518 ~ US MIN MGMT SERV, RESOURCE STUDIES AK OCS REGN KIRK W SHERWOOD 949 E 36TH AV RM 603 ANCHORAGE, AK 99508-4302 REGIONAL SUPRVISOR, FIELD OPERATION, MMS ALASKA OCS REGION 949 E 36TH AV STE 308 ANCHORAGE, AK 99508-4363 JOHN MILLER 3445 FORDHAM DR ANCHORAGE, AK 99508-4555 PHILLIPS ALASKA INC., LAND MANAGER JIM RUUD P.O. BOX 100360 ANCHORAGE, AK 99510 PHILLIPS ALASKA INC., STEVE BENZLER ATO 1404 POBOX 100360 ANCHORAGE, AK 99510-0360 PETROLEUM INFO CORP, KRISTEN NELSON POBOX 102278 ANCHORAGE, AK 99510-2278 AL YESKA PIPELINE SERV CO, LEGAL DEPT 1835 S BRAGAW ANCHORAGE, AK 99512-0099 JWL ENGINEERING, JEFF LIPSCOMB 9921 MAIN TREE DR. ANCHORAGE, AK 99516-6510 DAVID CUSATO 600 W 76TH AV #508 ANCHORAGE, AK 99518 HALLIBURTON ENERGY SERV, MARK WEDMAN 6900 ARCTIC BLVD ANCHORAGE, AK 99518-2146 TESORO ALASKA COMPANY, PO BOX 196272 ANCHORAGE, AK 99519 ENSTAR NATURAL GAS CO, PRESIDENT TONY IZZO POBOX 190288 ANCHORAGE, AK 99519-0288 UNOCAL, POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA) INC, MR. DAVIS, ESQ POBOX 196612 MB 13-5 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, SUE MILLER POBOX 196612 MIS LR2-3 ANCHORAGE, AK 99519-6612 PINNACLE, STEVE TYLER 20231 REVERE CIRCLE EAGLE RIVER, AK 99577 JAMES RODERICK PO BOX 770471 EAGLE RIVER, AK 99577-0471 PHILLIPS PETROLEUM CO. ALASKA OPERATIONS MANAGER J W KONST P 0 DRAWER 66 KENAI, AK 99611 KENAI PENINSULA BOROUGH, ECONOMIC DEVEL DISTR STAN STEADMAN POBOX 3029 KENAI, AK 99611-3029 BELOWICH, MICHAEL A BELOWICH 1125 SNOW HILL AVE WASILLA. AK 99654-5751 ~. OPSTAD & ASSOC, ERIK A OPSTAD PROF GEOL POBOX 190754 ANCHORAGE, AK 99519 MARATHON OIL COMPANY, OPERATIONS SUPT W.C. BARRON POBOX 196168 ANCHORAGE, AK 99519-6168 UNOCAL, KEVIN TABLER POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA) INC, INFO RESOURCE CTR MB 3-2 POBOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA), INC., MARK BERLINGER MB 8-1 PO BOX 196612 ANCHORAGE, AK 99519-6612 L G POST O&G LAND MGMT CONSULT 10510 Constitution Circle EAGLE RIVER, AK 99577 DEPT OF NATURAL RESOURCES, DGGS JOHN REEDER POBOX 772805 EAGLE RIVER, AK 99577-2805 RON DOLCHOK POBOX 83 KENAI, AK 99611 NANCY LORD PO BOX 558 HOMER, AK 99623 JAMES GIBBS POBOX 1597 SOLDOTNA, AK 99669 .~ JACK 0 HAKKILA POBOX 190083 ANCHORAGE, AK 99519-0083 MARATHON OIL COMPANY, LAND BROCK RIDDLE POBOX 196168 ANCHORAGE, AK 99519-6168 EXXONMOBIL PRODUCTION COMPANY, MARK P EVANS PO BOX 196601 ANCHORAGE, AK 99519-6601 BP EXPLORATION (ALASKA) INC, PETE ZSELECZKY LAND MGR POBOX 196612 ANCHORAGE, AK 99519-6612 AMSINALLEE CO INC, WILLIAM 0 VALLEE PRES PO BOX 243086 ANCHORAGE, AK 99524-3086 D A PLATT & ASSOC, 9852 LITTLE DIOMEDE CIR EAGLE RIVER, AK 99577 COOK INLET KEEPER, BOB SHAVELSON PO BOX 3269 HOMER, AK 99603 DOCUMENT SERVICE CO, JOHN PARKER POBOX 1468 KENAI, AK 99611-1468 PENNY VADLA POBOX 467 NINILCHIK, AK 99639 PACE, SHEILA DICKSON POBOX 2018 SOLDOTNA, AK 99669 KENAI NATL WILDLIFE REFUGE, REFUGE MGR POBOX 2139 SOLDOTNA, AK 99669-2139 VALDEZ VANGUARD, EDITOR POBOX 98 VALDEZ, AK 99686-0098 UNIV OF ALASKA FAIRBANKS, PETR DEVEL LAB DR V A KAMATH 427 DUCKERING FAIRBANKS, AK 99701 FAIRBANKS DAILY NEWS-MINER, KATE RIPLEY POBOX 70710 FAIRBANKS, AK 99707 K&K RECYCL INC, POBOX 58055 FAIRBANKS, AK 99711 UNIV OF ALASKA FBX, PETR DEVEL LAB SHIRISH PATIL 437 DICKERING FAIRBANKS, AK 99775 DEPT OF ENVIRON CONSERV SPAR, CHRIS PACE 410 WILLOUGHBY AV STE 105 JUNEAU, AK 99801-1795 ~ VALDEZ PIONEER, POBOX 367 VALDEZ. AK 99686 EVERGREEN WELL SERVICE CO., JOHN TANIGAWA PO BOX 871845 WASILLA, AK 99687 COOK AND HAUGEBERG, JAMES DIERINGER, JR. 119 NORTH CUSHMAN, STE 300 FAIRBANKS, AK 99701 C BURGLIN POBOX 131 FAIRBANKS, AK 99707 ASRC, BILL THOMAS POBOX 129 BARROW, AK 99723 UNIVERSITY OF ALASKA FBKS, PETR DEVEL LAB DRAKANNI LAWAL POBOX 755880 FAIRBANKS, AK 99775-5880 ~ AL YESKA PIPELINE SERVICE CO, VALDEZ CORP AFFAIRS SANDY MCCLINTOCK POBOX 300 MS/701 VALDEZ, AK 99686 NICK STEPOVICH 543 2ND AVE FAIRBANKS, AK 99701 RICK WAGNER POBOX 60868 FAIRBANKS, AK 99706 DEPT OF NATURAL RESOURCES, DIV OF LAND REG MGR NORTHERN REGION 3700 AIRPORT WAY FAIRBANKS, AK 99709-4699 RICHARD FINEBERG PO BOX416 ESTER, AK 99725 SENATOR LOREN LEMAN STATE CAPITOL RM 113 JUNEAU,AK 99801-1182 X13 • Chevron Paul Winslow Petroleum Engineer Advisor MidContinent/Alaska SBU Chevron North America Exploration and Production 3800 Centerpoint Dr., Ste 100 Anchorage, AK 99503 Tel (907) 263-7629 Email pwinslow@chevron.com February 22, 2010 FEB 2 3 2010 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission pp~~(;p~~g,Cotwfllldsaial 333 W. 7t" Avenue, Suite 100 R11d1pI~e Anchorage, AK 99501 Re: 2009 Annual Material Balance Calculations of Production and Injection Volumes Swanson River Gas Storage Facility #3 (Tyonek 77-3 sand) Swanson River Field Dear Commissioner Seamount: Attached for your review is the annual material balance calculation of production and injection volumes for the Swanson River Gas Storage Facility #3 (SRGSF #3), as required per AOGCC Storage Injection Order #6 (SIO #6). SRGSF #3 applies to the Tyonek 77-3 reservoir, which has had four wells completed in it, SCU 42A-05, SCU 42B-05, SCU 42-05X, and SCU 42-05Y. This material balance report covers the primary production period (Jul. 2004 -Nov. 2005), as well as the gas storage operations that have taken place since Dec. 2005. Attachment #1 is a table of gas production and injection volumes for the SCU 42A-05, SCU 42B-05, SCU 42-05X, and SCU 42-05Y wells, from the commencement of primary production, through February 21, 2010. Note that the January and February 2010 volumes are estimates from daily metered values. Historic reservoir pressure estimates have been obtained primarily through surface shut-in tubing pressure (SITP) readings, which were then converted to bottomhole pressures. In addition to the SITP's, downhole pressure gauges have been run several times, to obtain static bottomhole pressures and/or to conduct pressure transient tests. These data points are tabulated in Attachment #2 and plotted versus the corresponding net cumulative production on the standard P/Z plot (Attachment #3). Viewing Attachment #3, it has previously been noted that the early injection cycle pressures deviate above the straight line path established from the primary depletion points. Previous Annual Performance Reports have also documented that the production volumes/pressures have deviated below the primary depletion path. The latest 2009 injection and 2009/2010 production cycles mimicked the previously established injection and production trends, indicating the continued containment of the gas storage volumes. During the peak of the 2008/2009 winter production season (Oct. '08 -Mar. '09), a net total of 1,461 MMcf of gas was produced from the 77-3 reservoir. From Apr. -Oct. '09, a net total of 1,674 MMcf of gas was injected back into storage, via the SCU 42-05X and SCU 42-05Y MidContinent/Alaska SBU/Chevron North America Exploration and Production www.chevron.com • Swanson River Gas Storage Facility #3 2009 Annual Performance Report Page 2 wellbores. To date (2/21/09) an estimated total of 330 MMcf of gas has been withdrawn from storage (from the 77-3 reservoir) during the 2009/2010 winter season. If you have any questions regarding this annual performance report, please contact Paul Winslow at your earliest convenience. Sincerely, ~~~_ ~~~ Paul M. Winslow Petroleum Engineer Advisor Cc: Dave Whitacre Attachments Union Oil Company of California / A Chevron Company http://www.chevron.com • ATTACHMENT #1 SRGSF #3 -PRODUCTION AND INJECTION VOLUMES (TYONEK 77-3 SAND) onth SCU 42A-05 Monthly Monthly Gas Gas Inj Prod MCF MCF SCU 42B-05 Monthly Monthly Gas Gas Inj Prod MCF MCF SCU 42-05X Monthly Monthly Gas Gas Inj Prod MCF MCF SCU 42-05Y Monthly Monthly Gas Gas Inj Prod MCF MCF Tvonek 77-3 Sand Totals Cum Depletion Inventor (Prod-Inj) (Primary- Depl Vol) Cum for POZ Total Gas Plotting Inventory MCF MCF Jun-04 0 0 2,377,000 Jul-04 0 55,040: 55,040 2,321,960 Aug-04 0 194,185 249,225 2,127,775 Sep-04 0 173,352 422,577 1,954,423 Oct-04 0 151,770 574,347 1,802,653 Nov-04 0 161,949 736,296 1,640,704 Dec-04 0 116,582 852,878 1,524,122 Jan-05 0 160,730 1,013,608 1,363,392 Feb-05 0 160,235 1,173,843 1,203,157 Mar-05 0 164,902 1,338,745 1,038,255 Apr-05 0 156,158 1,494,903 882,097 May-05 0 172,327 1,667,230 709,770 Jun-05 0 162,359 1,829,589 547,411 Jul-05 0 157,953 1,987,542 389,458 Aug-05 0 114,531 i' 2,102,073 274,927 Sep-05 0 71,034 2,173,107 203,893 Oct-05 0 113,342 0 2,286,449 90,551 Nov-05 0 53,196 0 20,267 2,359,912 17,088 Dec-05 0 0 224,142 16,950 2,152,720 224,280 Jan-06 0 31,872 22,827 433 2,162,198 214,802 Feb-06 0 17,334 172 0 2,179,360 197,640 Mar-O6 0 87,263-`'< : 24,813 99,300 2,341,110 35,890 Apr-06 0 30,355 0 106,863 2,478,328 -101,328 May-06 0 0 311,189 8 2,167,147 209,853 Jun-06 0 0 12,011 0 2,155,136 221,864 Jul-06 0 863 0 0 0 35,263 2,191,262 185,738 Aug-06 0 131 0 0 331,869 6,215 - 1,865,739 511,261 Sep-06 0 0 0 0 422,802 0 1,442,937 934,063 Oct-06 110,657 0 1,332,280 1,044,720 Nov-06 83,366 66,196 1,315,110 1,061,890 Dec-06 200,905 12,889 1,127,094 1,249,906 Jan-07 156,326 70,834 1,041,602 1,335,398 Feb-07 106,193 56,748 992,157 1,384,843 Mar-07 54,252 88,933 1,026,838 1,350,162 Apr-07 247,449 0 779,389 1,597,611 May-07 74,062 0 705,327 1,671,673 Jun-07 82,060 0 623,267 1,753,733 Jul-07 39,731 103 583,639 1,793,361 Aug-07 139 0 0 18,925 602,425 1,774,575 Sep-07 134,187 0 0 35,500 503,738 1,873,262 Oct-07 41,803 64 " 0 0 461,999 1,915,001 Nov-07 0 29,621' ' 0 0 491,620 1,885,380 Dec-07 19,505 171,247 0 35,047 678,409 1,698,591 Jan-08 3,691 227,468 0 228,082 1,130,268 1,246,732 Feb-08 117,547 120,442 - , 0 180,632 1,313,795 1,063,205 Mar-08 239,096 24,957- 0 5,280 1,104,936 1,272,064 Apr-08 223,992 12,168 0 5,255 898,367 1,478,633 May-08 212,951 414_ 0 0 685,830 1,691,170 Jun-08 117,095 0 0 0 568,735 1,808,265 Jul-08 75,423 0 0 0 493,312 1,883,688 Aug-08 44,900 0 0 0 448,412 1,928,588 Sep-O8 24,393 448 0 0 424,467 1,952,533 Oct-08 9,943 47,208 0 80,068 541,800 1,835,200 Nov-08 1,267 222,108 0 94,718 857,359 1,519,641 Deo-08 716 223,913 0 312,349 1,392,905 984,095 2/22/2010 42 a-05 b-05 42-05x y prod inj updated 2-15-10.x1s • • ATTACHMENT #1 SRGSF #3 -PRODUCTION AND INJECTION VOLUMES (TYONEK 77-3 SAND) SCU 42A-05 SCU 42B-05 SCU 42-05X SCU 42-05Y Tvonek 77-3 Sand Totals Cum Depletion Inventory Monthly Monthly Monthly Monthly Monthly Monthly Monthly Monthly (Prod-Inj) (Primary- Depl Vol) Gas Gas Gas Gas Gas Gas Gas Gas Cum for POZ Total Gas Inj Prod Inj Prod Inj Prod Inj Prod Plotting Inventory Month MCF MCF MCF MCF MCF MCF MCF MCF MCF MCF Jan-09 96,694 127,939 0 182,169 1,606,319 770,681 Feb-09 80,773 89,080 0 132,598 1,747,224 629,776 Mar-09 1,687 46,556 0 92,950 1,885,043 491,957 Apr-09 66,627 59 ` 4,052 570 1,814,993 562,007 May-09 348,664 0 '; 383,772 0 1,082,557 1,294,443 Jun-09 162,392 0 188,982 0 731,183 1,645,817 Jul-09 89,080 0 84,826 0 557,277 1,819,723 Aug-09 84,595 0 69,382 0 403,300 1,973,700 Sep-09 65,793 0 36,978 0 300,529 2,076,471 Oct-09 54,863 813 34,950 0 211,529 2,165,471 Nov-09 35,841 62,754 42,943 59,369 254,868 2,122,132 Dec-09 50,849 90,554 2,773 33,242 325,042 2,051,958 Jan-10 9,544 74,174 1,214 50,434 438,892 1,938,108 Feb-10 0 22,766 0 79,558 541,216 1,835,784 January and February (thru 2/21) 2010 volumes are estimated from daily metered readings 2/22/2010 42 a-05 b-05 42-05x y prod inj updated 2-15-10.x1s C~ • ATTACHMENT #2 SRGSF #3 - P/Z VS. CUM PRODUCTION DATA (Tyonek 77-3 Sand) Parameter Value Units Gas Gravity 0.563 Bench Datum 7811 ft (tvd) Datum Temp. 141 °F Datum Temp. 601 °R Initial Z Guess 0.88 auge Test Measured Datum Duration Test Depth Pressure at Pressure, Wellname Date Test Type (hrs) (MTD), ft MTD, psis Z Factor Psia Cum Gas, bcf P/Z, Psia Primary Production 42A-5 06/27/04 Surf PBU 1 0 3994 0.9803 4774 0.0000 4870 42A-5 10/22/04 Surf PBU 1 0 3050 0.9110 3646 0.5354 4002 42A-5 12/21/04 BHP Static 1 7982 3194 0.8933 3194 0.8403 3576 42A-5 2/8/2005 BHP PBU 8 7982 2482 SITP 0.8859 2926 1.0599 3303 42A-5 06/23/05 BHP PBU 8 7811 1985 0.8835 1985 1.7931 2247 42A-5 07/11/05 SITP 2 0 1565 0.8859 1871 1.8881 2112 42A-5 08/25/05 SITP 3 0 1385 0.8923 1655 2.1024 1855 42A-5 09/13/05 SITP 3 0 1490 0.8883 1781 2.1051 2005 42A-5 10/25/05 BHP PBU 8 7811 1556 0.8959 1556 2.2666 1737 2005 Iniection Cvcle 142A&B-5 I 1/4/2006 IBHP Static 142 17811 11857 10.8803 I 2232 I 2.1423 I 2536 I 2006 Production Cycle 42A&B-5 3/10/2006 SITP 4 0 1895 0.8802 2236 2.1633 2540 42A&B-5 3/18/2006 BHP Static 1 7811 2026 0.8827 2026 2.2260 2295 42B-5 4/12/2006 BHP Static 42a- 120 0 1412 0.8911 1689 2.4038 1895 426-5 5/4/2006 SITP 96 0 1280 0.8969 1530 2.4783 1706 2006-2007 Injection Cycle 42A&B-5 5/17/2006 SITP 48 0 1528 0.8871 1826 2.3799 2058 42A5 6/9/2006 Psuedo SITP 192 0 2010 0.8797 2403 2.1551 2732 42-05X 8/3/2006 SITP/ BHP PBU 15 0 1875 0.8801 2256 2.1976 2563 42-05X 8/24/2006 SITP/BHP PFO 12 0 2400 0.8851 2886 1.9949 3261 42-05X 9/7/2006 SITP 24 0 2826 0.9004 3396 1.7610 3772 42-05X 9/26/2006 SITP 24 0 3347 0.9290 4000 1.4678 4306 42-05X 10/3/2006 SITP 53 0 3312 0.9267 3958 1.4422 4271 42-05X 10/6/2006 SITP 11 0 3309 0.9265 3955 1.4390 4269 42-05X 10/17/2006 SITP 107.5 0 3245 0.9234 3896 1.4127 4219 42-05X 10/20/2006 BHP PFO 8 7794 3241 0.9216 3862 1.4015 4191 42-05X 11/8/2006 SITP 31.5 0 3445 0.9358 4118 1.2840 4401 42-05X 11/16/2006 SITP 44.5 0 3403 0.9328 4067 1.2497 4360 42-05X 1/7/2007 SITP 89 0 3469 0.9374 4146 1.1109 4423 42-05X 4/20/2007 SITP 20 0 3794 0.9626 4534 0.8318 4710 42-05X 5/22/2007 SITP 8 0 3755 0.9583 4473 0.7523 4668 42-05X 8/28/2007 SITP 12 0 3715 0.9561 4440 0.5834 4644 42-05X 11/26/2007 SITP 840 0 3815 0.9644 4560 0.4622 4728 2008 Production. Cycle 42-05X 12/14/2007 SITP 89.5 0 3647 0.9507 4359 0.5166 4585 42-05X 1/4/2008 SITP 31 0 3258 0.9231 3890 0.6896 4214 42-05X 1/23/2008 SITP 7 0 2676 0.8934 3199 0.9690 3581 42-05X 2/8/2008 SITP 10 0 1990 0.8797 2379 1.2923 2704 42-05Y 2/13/2008 SITP 27.3 0 1909 0.8800 2282 1.3859 2593 2/22/2010 SCU 42-05 77-3 Sd POZ 2-17-10.x1s C~ ATTACHMENT #2 SRGSF #3 - P/Z VS. CUM PRODUCTION DATA (Tyonek 77-3 Sand) Parameter Value Units Gas Gravity 0.563 Bench Datum 7811 ft (tvd) Datum Temp. 141 °F Datum Temp. 601 °R Initial Z Guess 0.88 auge Test Measured Datum Duration Test Depth Pressure at Pressure, Wellname Date Test Type (hrs) (MTD), ft MTD, psia Z Factor Psia Cum Gas, bcf P/Z, Psia 2008 Iniectionn Cvcle 42-05Y 5/16/2008 SITP 24 0 3668 0.9476 4311 0.783 4549 42-05Y 6/6/2008 SITP 216 0 3771 0.9552 4427 0.686 4635 42-05Y 7/6/2008 SITP 96 0 3915 0.9663 4587 0.567 4747 42-05Y 9/22/2008 SITP 96 0 3796 0.9571 4455 0.431 4655 42-05Y 10/7/2008 SITP 96 0 3857 0.9618 4523 0.427 4703 2008 / 2009 Production Cvcle 42-05X & Y 11/13/2008 SITP 72 0 3214 0.9182 3796 0.660 4134 42-05X & Y 11/30/2008 SITP 24 0 2847 0.8995 3372 0.853 3749 42-05Y 12/8/2008 SITP 96 0 2719 0.8942 3222 0.941 3603 42-05Y 1/14/2009 SITP 24 0 1518 0.8880 1792 1.654 2018 42-05X & Y 4/21/2009 SITP 336 0 1799 0.8740 2148 1.886 2458 2009 Injection Cycle 42-05X & Y 11/11/2009 SITP 192 0 4256 0.9922 4967 0.211 5006 2009 / 2010 Production Cvcle 42-05X & Y 12/7/2009 SITP 30 0 4102 0.9808 4808 0.253 4902 42-05X & Y 1/10/2010 SITP 48 0 3834 0.9604 4512 0.346 4698 42-05X & Y 1/19/2010 SITP 48 0 3750 0.9543 4419 0.380 4631 2/22/2010 SCU 42-05 77-3 Sd POZ 2-17-10.x1s ATTACHMENT #3 SRGSF #3 - POZ vs Cum Gas Production Plot (Tyonek 77-3 Sand) 6000 5000 4000 ~~- . • °,, ~ _-~~; • Primary Prod •'05 '06 Inj Cycle •'06 Prod Cycle •'06-'07 Inj Cycle ~ ~ •'07-'08 Prod Cycle ~ - •'08 Inj Cycle • '08 '09 Prod Cycle •'09 Inj Cycle _____ •'09-'10 Prod Cycle eo .y °~ 3000 N a 2000 1000 0 ~ 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 Cum Gas Produced, bcf it 2/22/20100:\NAU\MCBU\Alaska\Depts\AssetDev\CIGas\Gas CFT\Openmind\Swanson\Soldotna Creek Unit North\SCU42A- 5\Surveys\PressureWOGCC Annual Mat Bal Rpt\2009\SCU 42-05 77-3 Sd POZ 2-17-10.x1s AOGCC (100223) ~12 . . ~ ;--"1 :itU1;r ~~'ì j¡ 0U 1-( :1 L: 11 j'r ¡, '1'1 U .l2::t FRANK H. MURKOWSKI, GOVERNOR A.1'4A.SIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 27, 2004 Proposals to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells The Alaska Oil and Gas Conservation Commission ("Commission"), on its own motion, proposes to amend the rules addressing mechanical integrity of wells in all existing area injection orders, storage injection orders, enhanced recovery injection orders, and disposal injection orders. There are numerous different versions of wording used for each of the rules that create confusion and inconsistent implementation of well integrity requirements for injection wells when pressure communication or leakage is indicated. In several injection orders, there are no rules addressing requirements for notification and well disposition when a well integrity failure is identified. Wording used for the administrative approval rule in injection orders is similarly inconsistent. The Commission proposes these three rules as replacements in all injection orders: Demonstration of Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before Injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and before returning a well to service following a workover affecting mechanical integrity. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 minute period. The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. . . Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. The following table identifies the specific rules affected by the rewrite. Affected Rules Injection Order "Demonstration of "Well Integrity "Administrati ve Mechanical Failure and Action" Integrity" Confinement" Area In.iection Orders AIO 1 - Duck Island Unit 6 7 9 AIO 2B - Kuparuk River Unit; Kuparuk River, 6 7 9 Tabasco, Ugnu, West Sak Fields AIO 3 - Prudhoe Bay Unit; 6 7 9 Western Operatin.e; Area AIO 4C - Prudhoe Bay Unit; 6 7 9 Eastern Operating Area AIO 5 - Trading Bay Unit; 6 6 9 McArthur River Field AIO 6 - Granite Point Field; 6 7 9 Northern Portion AIO 7 - Middle Ground 6 7 9 Shoal; Northern Portion AIO 8 - Middle Ground 6 7 9 Shoal; Southern Portion AIO 9 - Middle Ground 6 7 9 Shoal; Central Portion AIO lOB - Milne Point Unit; Schrader Bluff, Sag River, 4 5 8 Kuparuk River Pools AIO 11 - Granite Point 5 6 8 Field; Southern Portion AIO 12 - Trading Bay Field; 5 6 8 Southern Portion AIO 13A - Swanson River 6 7 9 Unit AIO 14A - Prudhoe Bay 4 5 8 Unit; Niakuk Oil Pool AIO 15 - West McArthur 5 6 9 . . Affected Rules "Demonstration of "Well Integrity "Administrative Injection Order Mechanical Failure and Action" Integrity" Confinement" River Unit AIO 16 - Kuparuk River 6 7 10 Unit; Tarn Oil Pool 6 8 AIO 17 Badami Unit 5 AIO 18A - Colville River 6 7 11 Unit; Alpine Oil Pool AIO 19 - Duck Island Unit; 5 6 9 Eider Oil Pool AIO 20 - Prudhoe Bay Unit; 5 6 9 Midnight Sun Oil Pool AIO 21 - Kuparuk River 4 No rule 6 Unit; Meltwater Oil Pool AIO 22C - Prudhoe Bay 5 No rule 8 Unit; Aurora Oil Pool 6 9 AID 23 Northstar Unit 5 AIO 24 - Prudhoe Bay Unit; 5 No rule 9 Borealis Oil Pool AIO 25 - Prudhoe Bay Unit; 6 8 13 Polaris Oil Pool AIO 26 - Prudhoe Bay Unit; 6 No rule 13 Orion Oil Pool Disposal Iniection Orders DIO 1 - Kenai Unit; KU No rule No rule No rule WD-l DIO 2 - Kenai Unit; KU 14- No rule No rule No rule 4 DIO 3 - Beluga River Gas No rule No rule No rule Field; BR WD-l DIO 4 - Beaver Creek Unit; No rule No rule No rule BC-2 DIO 5 - Barrow Gas Field; No rule No rule No rule South Barrow #5 DIO 6 - Lewis River Gas No rule No rule 3 Field; WD-l DIO 7 - West McArthur 2 3 5 River Unit; WMRU D-l DIO 8 - Beaver Creek Unit; 2 3 5 BC-3 DID 9 - Kenai Unit; KU 11- 2 3 4 17 DID 10 - Granite Point 2 3 5 Field; GP 44-11 . . Affected Rules "Demonstration of "Well Integrity "Administrative Injection Order Mechanical Failure and Action" Integrity" Confinement" DIO 11 - Kenai Unit; KU 2 3 4 24-7 DIO 12 - Badami Unit; WD- 2 3 5 1, WD-2 DIO 13 - North Trading Bay 2 3 6 Unit; S-4 DIO 14 - Houston Gas 2 3 5 Field; Well #3 DIO 15 - North Trading Bay 2 3 Rule not numbered Unit; S-5 DIO 16 - West McArthur 2 3 5 River Unit; WMRU 4D DIO 17 - North Cook Inlet 2 3 6 Unit; NCIU A-12 DIO 19 - Granite Point 6 Field; W. Granite Point State 3 4 17587 #3 DIO 20 - Pioneer Unit; Well 3 4 6 1702-15DA WDW DIO 21 - Flaxman Island; 3 4 7 Alaska State A - 2 DIO 22 - Redoubt Unit; RU 3 No rule 6 D1 DIO 23 - Ivan River Unit; No rule No rule 6 IRU 14-31 DIO 24 - Nicolai Creek Order expired Unit; NCU #5 DIO 25 - Sterling Unit; SU 3 4 7 43-9 DIO 26 - Kustatan Field; 3 4 7 KFl Stora2e Injection Orders SIO 1 - Prudhoe Bay Unit, No rule No rule No rule Point McIntyre Field #6 SIO 2A- Swanson River 2 No rule 6 Unit; KGSF #1 SIO 3 - Swanson River Unit; 2 No rule 7 KGSF #2 Enhanced Recovery In.iection Orders EIO 1 - Prudhoe Bay Unit; No rule 8 Prudhoe Bay Field, Schrader No rule Bluff Formation Well V-I05 . . Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Integrity" Confmement" EIO 2 - Redoubt Unit; RU-6 5 8 9 · . 'I I 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AOFRM STATE OF ALASKA ADVERTISING ORDER NOTICE TO PUBLISHER ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO, CERTIFIED AO"02 514016 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COpy OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE AOGCC R 333 West ih Avenue, Suite 100 o Anchorage,AK 99501 M 907-793-1221 AGENCY CONTACT DATE OF A.O. PHONE PC T o Journal of Commerce 301 Arctic Slope Ave #350 Anchorage, AK 99518 October 3,2004 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: United states of America AFFIDAVIT OF PUBLICATION REMINDER State of ss 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. 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 day of 2004, and thereafter for _ consecutive days, the last publication appearing on the _ day of , 2004, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This _ day of 2004, Notary public for state of My commission expires Public Notices . . Subject: Public Notices From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Wed, 29 Sep2004 13:01 :04 -0800 10f2 9/29/20041:10 PM Public Notices . . 20f2 9/29/2004 I: 10 PM Public Notice . . Subject: Public Notice From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: 29 2004 12:55:26 -0800 Please publish the attached Notice on October 3, 2004. Thank you. Jody Colombie . Mechanical Integrity of Wells Content-Type: applicationlmsword Content-Encoding: base64 Content- Type: applicationlmsword Ad Order form.doc Content-Encoding: base64 1 of 1 9/29/2004 1:10 PM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 . Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 . /lJetlkd (tJ/}tlJ David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue SOldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 .[Fwd: Re: Consistent Wording for Injection. - Well Integrity .'. . Subject: [Fwd: Re: Consistent Wording for Injection Orders - Well Integrity (Revised)] From: John Norman <john _norman@admin.state.ak.us> Date: Fri, 01 Oct 2004 11 :09:26 -0800 more -------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - Well Integrity (Revised) Date:Wed, 25 Aug 2004 16:49:40 -0800 From:Rob Mintz <robert mintz@)law.state.ak.us> To: i im regg(âJadmin. state. ak. us CC :dan seamount(âJadmin.state.ak. us, john norman(âJadmin.state.ak. us Jim, looks good, but I still think maybe it would be good to include the following sentence or something like it in the well integrity and confinement rule: "The operator shall shut in the well if so directed by the Commission." My thinking is that otherwise, an operator might argue that the Commission can only require the well to be shut in by going through an enforcement action, issuing an order after notice and opportunity for hearing, or meeting the strict requirements for an emergency order under the regulations. The proposed language makes clear that it is a condition of the authorization to inject, that the operator must shut in the well if directed by the Commission after a notification of loss of integrity, etc. »> James Regg <iim regg@admin.state.ak.us> 8/25/2004 3:15:06 PM »> Rob - Thanks for the review; here's a redraft after considering your comments. I have accepted most of the suggested edits; also attached is response to questions you pose (responses are embedded in the comments, using brackets (JBR - ...) to set apart from your questions). Jim Regg Rob Mintz wrote: Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <jim regg@admin.state.ak.us> 8/17/20044:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing lof2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injectieders - Well Integrity ... . - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions - adopts "Administrative Actions" title (earlier rules used "Administrative Relief"); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDW s"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Norman <John Norman~admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission 20f2 10/2/2004 4:07 PM . .[Fwd: Re: Consistent Wording for Injection 0.- Well Integrity... . Subject: [Fwd: Re: Consistent Wording for Injection Orgen; .. WëlIrntegritY(Revised») ~r()m:. John Norman <john--,norman@admin.state.ak.µs> Date: Fri, 01 Oct 2004 11:08:55 -0800 please print all and put in file for me to review just prior to hearing on these amendments. thanx -------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - Well Integrity (Revised) Date:Thu, 19 Aug 200415:46:31 -0800 From:Rob Mintz <[obert mintz(G¿law.state.ak.us> To:dan seamount(G¿admin.state.ak.us, jim regg(G¿admin.state.ak.us, john norman(G¿admin.state.ak.us Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlínes on the second document attached. »> James Regg <iim regg@admin.state.ak.us> 8/17/20044:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points- Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing - specific to AlO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions lof2 10/2/20044:07 PM [Fwd: Re: Consistent Wording for Injecti.ers - Well Integrity ... . - adopts "Administrative Actions" title (earlier rules used "Administrative Relief'); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting" freshwater", "aquifers", "USDW s"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Norman <John Norman@admin.state.us> Commissioner Alaska Oil & Gas Cmservation Commission Content- Type: applicationlmsword Injection Order language - questions.doc Content-Encoding: base64 Content-Type: applicationlmsword Injection Orders language edits.doc Content-Encoding: base64 20f2 10/2/2004 4:07 PM . . Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, after a workover affecting mechanical integrity, and at least once every 4 years while actively injecting. For slurry injection wells, the tubing/casing annulus must be tested for mechanical integrity every 2 years. The MIT surface pressure must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, must show stabilizing pressure and may not change more than 10% during a 30 minute period. Any alternate means of demonstrating mechanical integrity must be approved by the Commission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement The tubing, casing and packer of an injection well must demonstrate integrity during operation. The operator must immediately notify the Commission and submit a plan of corrective action on Form 10-403 for Commission approval whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, or log. If there is no threat to freshwater, injection may continue until the Commission requires the well to be shut in or secured. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. . . Standardized Language for Injection Orders Date: August 17,2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once everv two years in the case of a slurry injection well), and before returning a weIl to service following a#ef a workover affecting mechanical integrity, and at least once every '1 year:; '?.-hile actively injecting. For slurry injection 'sells, the tubing/casing ar.nulus must be tested for mechanical integrity every 2 years. Unless an alternate means is approved bv the Commission. mechanical integrity must be demonstrated by a tubing pressure test using a ~ M++--surface pressure of must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, that ffH:}St-showâ stabilizing pressure that does:md may not change more than 10%- percent during a 30 minute period. -À:fly alternate means of demonstrating mechanical integrity must be approved by the Commission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement Except as otherwise provided in this rule. +1he tubing, casing and packer of an injection well must demonstrate maintain integrity during operation. ·Whenever any pressure communication. leakage or lack of injection zone isolation is indicated by injection rate. operating pressure observation. test, survey, log. or other evidence. t+he operator fI'lttSt-shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval" \vhencver an)' pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure obser';ation, test, survey, or log. The operator shall shut in the well if so directed by the Commission. The operator shall shut in the well \vithout awaiting a response from the Commission if continued operation would be unsafe or would threaten contamination of freshwaterIf there is no threat to frcshv..·ater, injection may continue until the Commission requires the ',1.-ell to be shut in or secured. Until corrective action is successfully completed. Aª monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. JF:d: Re: [Fwd: AOGCC Proposed WI Lang.or Injectors]] . SllbJect: [Fwd: Re:. [Fwd: AOGCCProposedWILanguage for Injectors]] Fr<!~:Winton Aubert <winton:.-aubert@adrnin.state.ak.us> Dáte: Thu,28Qct 200409:48:53..-08QO This is part of the record for the Nov. 4 hearing. WGA -------- Original Message -------- Subject: Re: [Fwd: AOGCC Proposed WI Language for Injectors] Date: Thu, 28 Oct 2004 09:41:55 -0800 From: James Regg <jim regg@admin.state.ak.us> Organization: State of Alaska To: Winton Aubert <winton aubert@admin.state.ak.us> References: <41812422.8080604@admin.state.ak.us> These should be provided to Jody as part of public review record Jim Winton Aubert wrote: FYI. -------- Original Message -------- AOGCC Proposed WI Language for Tue, 19 Oct 2004 13:49:33 -0800 Engel, Harry R <EngelHR@BP.com> winton aubert@admin.state.ak.us Injectors Subject: Date: From: To: Winton... Here are the comments we discussed. Harry *From: * NSU, ADW Well Integrity Engineer *Sent: * Friday, October 15, 2004 10:43 PM *To: * Rossberg, R Steven¡ Engel, Harry R¡ Cismoski, Doug A¡ NSU, ADW Well Operations Supervisor *Cc: * Mielke, Robert L.¡ Reeves, Donald F¡ Dube, Anna T¡ NSU, ADW Well Integrity Engineer *Subject: * AOGCC Proposed WI Language for Injectors Hi Guys. John McMullen sent this to us, it's an order proposed by the AOGCC to replace the well integrity related language in the current Area Injection Orders. Listed below are comments, not sure who is coordinating getting these in front of Winton/Jim. Overall, looks okay from an Operations perspective. We do have a few comments, but could live with the current proposed language. Note the proposed public hearing date is November 4. The following language does not reflect what the slope AOGCC inspectors are currently requiring us to do: "The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and * before*_** 100 10/28/200411:09 AM [Fwd: Re: [Fwd: AOGCC Proposed WI Lege for Injectors]] . return::.ng a well to service following a workover affecting mechanical integrity." After a workover, the slope AOGCC inspectors want the well warmed up and on stable injection, then we conduct the AOGCC witnessed MITIA. This language requires the AOGCC witnessedMITIA before starting injection, which we are doing on the rig after the tubing is run. Just trying to keep language consistent with the field practice. If "after" was substituted for "before", it would reflect current AOGCC practices. It would be helpful if the following language required reporting by the "next working day" rather than "immediately", due to weekends, holidays, etc. We like to confer with the APE and get a plan finalized, this may prevent us from doing all the investigating we like to do before talking with the AOGCC. "Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall * immediately* ** notify the Commission" -- This section could use some help/wordsmithing: "A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation." Report content requirements are clear, but it's a little unclear what triggers a well to be included on this monthly report. Is it wells that have been reported to the AOGCC, are currently on-line and are going through the Administrative Action process? A proposed re-write would be: "All active injection wells with well integrity failure or lack of injection zone isolation shall have the following information reported monthly to the Commission: daily tubing and casing annuli pressures, daily injection rates." Requirements for the period between when a well failure is reported and when an administrative action is approved are unclear. This document states "the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403". If we don't plan to do any corrective action, but to pursue an AA, does a 10-403 need to be submitted? The AOGCC has stated they don't consider an AA as "corrective action". Let me know if you have any questions. Joe -----Original Message----- From: Kleppin, Daryl J Sent: Wednesday, September 29, 2004 1:37 PM To: Townsend, Monte Ai Digert, Scott Ai Denis, John R (ANC) i Miller, Mike Ei McMullen, John C Subject: FW: Public Notices FYI -----Original Message----- From: Jody Colombie [ mailto:jody colombie@admin.state.ak.us Sent: Wednesday, September 29, 2004 1:01 PM Subject: Public Notices Please find the attached Notice and Attachment for the proposed amendment of underground injection orders and the Public Notice Happy Valley #10. Jody Colombie «Mechanical Integrity proposal. ZIP» «Mechanical Integrity of Wells Notice.doc» 2 00 10/28/2004 11:09 AM #11 STATE OF ALASKA ADVERTISING ORDER f"""'. NOTICE TO PUBLISHER '\ ADVERTISING ORDER NO. INVO~UST BE IN TRIPLICATE SHOWING ADVERTISING ORDER ~ERTIFIED AO-02 314042 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COpy OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC R 333 W 7th Ave, Ste 100 0 Anchorage, AK 99501 M AGENCY CONTACT Jodv Colombie PHONE DATE OF A.O. April 10, 2003 PCN ~ Anchorage Daily News POBox 149001 Anchorage, AK 99514 (907) 793 -1 ?7.1 DATES ADVERTISEMENT REQUIRED: April 11,2003 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Type of Advertisement x Legal D Display Account #STOFO330 Advertisement to be published was e-mailed D Classified DOther (Specify) SEE ATTACHED PUBLIC HEARING ,&- ."-~- REF TYPE 1 VEN 2 ARD 3 4 NUMBER AOGCC, 333 W. 7th Ave., Suite 100 Anchora~e, AK. 99501 AMOUNT DATE - - - I ITOTALOF I PAGE 1 OF ALL PAGES$ 2 PAGES COMMENTS 02910 FIN AMOUNT Sy 03 cc 02140100 PGM LC ACCT 73540 FY NMR DIST UQ 1 2 3 4 REQUISITK)NED C' - \~~~~l \ . J --...., IDI~2~ - ; -./ 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM :arage Daily News Affidavit of Publication '~~ 1001 Northway Drive, Anchorage, AK 99508 PRICE OTHER OTHER OTHER OTHER OTHER GRAND AD# DATE PO ACCOUNT PER DAY CHARGES CHARGES#2 CHARGES #3 CHARGES #4 CHARGES #5 TOTAL 766241 04/11/2003 02314042 STOF0330 $149.46 $149.46 $0,00 $0.00 $0.00 $0.00 $0.00 $149.46 STATE OF ALASKA THIRD JUDICIAL DISTRICT Kimberly A. Kirby, being first duly sworn on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. Subscribed and lli4 /'""/'< om to me before this date: That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the armexed is a copy of an advertisement as it was published in regular issues (and not in supplemental fonn) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. Si~ed j¿¿( ø~~~ Notary Public in and for the State of Alaska. Third Division. Anchorage,'Alaska MY COMMISSION EXPIRES: M A{~{ ~f:3 \\ ..\ .\E 8 ,r,r/: ",\.\O~~"': ð.e. ~ "" '...' ~~ ~ ~~ ' , '-:L"" ::::::~OTAð .::~-::. " . ~ rt',....'- ". ... '... ~ : ÞuSUC : ~ -::;.~,"', ,_.. I.,'~~ ~ '~OF ~',Q>.:\, ~ ", "'.:..i.v~" //.1 ~JrrÌIfJS~:", :/}jiïTïìl\\\\ . . . ~ ~ Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of Union Oil Company of California ("Unocal") for an order authorizing the underground storage of hydrocarbons by injection into the Tyonek Formation in proposed well Swanson River Unit KGSF #3. Union Oil Company of California ("Unocal") by letter dated April 1, 2003, has applied for an injection order for storage injection well, Kenai Gas Storage Facility #3 ("KDSF #3"). The Commission has tentatively set a public hearing on this application for May 13,2003 at 9:00 am at the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on April 28, 2003. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. In addition, a person may submit written comments regarding this application to the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. Written comments must be received no later than 4:30 pm on May 12, 2003, except that if the Commission decides to hold a public hearing, written comments must be received no later than 9:00 am on May 13,2003. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact lody Colombie at 793-1221 befOreMaY1,20..03~~. ' ;'n n , c ~;y{/Jl '~d.~,---, Sarah Palin, Chair Published Date: April II, 2003 ADN AO# 02314042 Re: Ad Order r'¡ -. Subject: Re: Ad Order Date: 10 Apr 2003 11 :31 :11 -0800 From: Legal Ads Anchorage Daily News <legalads@adn.com> To: Jody Colombie <jody - colombie@admin.state.ak.us> Hi Jody: Following is the confirmation information on your legal notice. Please let me know if you need anything further. Account Number: STOF 0330 Legal Ad Number: 766241 Publication Date(s): April 11, 2003 Your Reference #: AO-02314042 Total: $149.46 Thank You, Kim Kirby Anchorage Daily News Legal Classified Representative E-Mail: legalads@adn.com Phone: (907) 257-4296 Fax: (907) 279-8170 On Thursday, April 10, 2003, Jody Colombie <jody_colombie@admin.state.ak.us> wrote: > >Please publish tomorrow. > > Jody 1 of 1 4/10/20033:25 PM STATE OF ALASKA ADVERTISING ORDER IN:¡UST BE I~~r~~~ S!~I~~~~~I~~:;aERTIFIED ADVERTISING ORDER NO. AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COpy OF AO-O2314042 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC R 333 West 7th Avenue, Suite 100 0 J\nchorage,AJ( 99501 M AGENCY CONTACT DATE OF A.O. Joci)' Colombie Ap~pril lO, ?0O3 PHOIIIE CN (907) 793 -12? 1 DATES ADVERTISEMENT REQUIRED: ~ J\nchorage Daily News POBox 149001 J\nchorage, AK 99514 April 11, 2003 THE MATERIAL BElWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Account #STOFO330 United states of America AFFIDAVIT OF PUBLICA TION REMINDER State of SS 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. 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 day of 2003, and thereafter for - consecutive days, the last publication appearing on the - day of . 2003. and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and swom to before me This - day of 2003, Notary public for state of My commission expires 02-901 (Rev. 3/94) Page 2 AO.FRM PUBLISHER Daniel Donkel 2121 North Bayshore Drive, Ste 1219 Miami, FL 33137 Jim Yancey Seal-Tite International 500 Deer Cross Drive Madisonville. LA 70447 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Paul Walker Chevron 1301 McKinney, Rm 1750 Houston, TX 77010 David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 T.E. Alford ExxonMobii Exploration Company PO Box 4778 Houston, TX 77210-4778 Chevron USA Alaska Division PO Box 1635 Houston, TX 77251 Shelia McNulty Financial Times PO Box 25089 Houston, TX 77265-5089 James White Intrepid Prod. Co.lAlaskan Crude 4614 Bohill SanAntonio, TX 78217 ~ SD Dept of Env & Natural Resources Oil and Gas Program 2050 West Main, Ste 1 Rapid City, SD 57702 Christine Hansen Interstate Oil & Gas Compact Comm Excutive Director PO Box 53127 Oklahoma City, OK 73152 Gregg Nady Shell E&P Company Onshore Exploration & Development PO Box 576 Houston, TX 77001-0576 G. Scott Pfoff Aurora Gas, LLC 10333 Richmond Ave, Ste 710 Houston, TX 77042 William Holton, Jr. Marathon Oil Company Law Department 5555 San Fecipe St. Houston, TX 77056-2799 Texico Exploration & Production PO Box 36366 Houston, TX 77236 Donna Williams World Oil Statistics Editor PO Box 2608 Houston, TX 77252 Shawn Sutherland Unocal Revenue Accounting 14141 Southwest Freeway Sugar Land, TX 77478 Doug Schultze XTO Energy Inc. 3000 North Garfield, Ste 175 Midland, TX 79705 ~. John Katz State of Alaska Alaska Governor's Office 444 North Capitol St., NW, Ste 336 Washington, DC 20001 Alfred James 200 West Douglas, Ste 525 Wichita, KS 67202 Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Michael Nelson Purvin Gertz, Inc. Library 600 Travis, Ste 2150 Houston, TX 77002 G. Havran Gaffney, Cline & Associations Library 1360 Post Oak Blvd., Ste 2500 Houston, TX 77056 W. Allen Huckabay ConocoPhillips Petroleum Company Offshore West Africa Exploration 600 North Dairy Ashford Houston, TX 77079-1175 Corry Woolington ChevronTexaco Land-Alaska PO Box 36366 Houston, TX 77236 Chevron Chemical Company Library PO Box 2100 Houston, TX 77252-9987 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Robert Gravely 7681 South Kit Carson Drive Littleton. CO 80122 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Cammy Taylor 1333 West 11th Ave. Anchorage, AK 99501 Duane Vaagen Fairweather 715 L Street, Ste 7 Anchorage, AK 99501 Tim Ryherd State of Alaska Department of Natural Resources 550 West 7th Ave., Ste 800 Anchorage, AK 99501 Ed Jones Aurora Gas, LLC Vice President 1029 West 3rd Ave., Ste 220 Anchorage, AK 99501 Mark Dalton HDR Alaska 2525 C Street, Ste 305 Anchorage, AK 99503 Mark Hanley. Anadarko 3201 C Street, Ste 603 Anchorage, AK 99503 Schlumberger Drilling and Measurements 3940 Arctic Blvd., Ste 300 Anchorage, AK 99503 .~ Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Thor Cutler OW-137 US EPA egion 10 1200 Sixth Ave. Seattle, WA 98101 Richard Mount State of Alaska Department of Revenue 500 West 7th Ave., Ste 500 Anchorage, AK 99501 Jim Arlington Forest Oil 310 K Street, Ste 700 Anchorage, AK 99501 William VanDyke State of Alaska Department of Natural Resources 550 West 7th Ave.. Ste 800 Anchorage, AK 99501 Trustees for Alaska 1026 West 4thAve., Ste 201 Anchorage, AK 99501-1980 Jack Laasch Natchiq Vice President Government Affairs 3900 C Street, Ste 701 Anchorage, AK 99503 John Harris NI Energy Development Tubular 3301 C Street, Ste 208 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 ~ Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 John F. Bergquist Babson and Sheppard PO Box 8279 Long Beach, CA 90808-0279 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Julie Houle State of Alaskan DNR Div of Oil & Gas. Resource Eval. 550 West 7th Ave., Ste 800 Anchorage, AK 99501 Susan Hill State of Alaska, ADEC EH 555 Cordova Street Anchorage, AK 99501 Robert Mintz State of Alaska Department of Law 1031 West 4th Ave., Ste 200 Anchorage, AK 99501 Mark Wadman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Rob Crotty C/O CH2M HILL 301 West Nothem Lights Blvd Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage. AK 99503 Judy Brady Alaska Oil & Gas Associates 121 West Firewead Lane. Ste 207 Anchorage, AK 99503-2035 Arlen Ehm 2420 Foxhall Dr. Anchorage, AK 99504-3342 Rose Ragsdale Rose Ragsdale & Associates 3320 E. 41st Ave Anchorage, AK 99508 Jim Scherr US Minerals Management Service Resource Evaluation 949 East 36th Ave., Ste 308 Anchorage, AK 99508 Chuck O'Donnell Veco Alaska,lnc. 949 East 36th Ave., Ste 500 Anchorage, AK 99508 Barbara Fullmer ConocoPhillips Alaska, Inc. Legal Department A TO 2084 PO Box 100360 Anchorage, AK 99510-0360 Jordan Jacobsen Alyeska Pipeline Service Company Law Department 1835 So. Bragaw Anchorage, AK 99515 Jeanne Dickey BP Exploration (Alaska), Inc. Legal Department PO Box 196612 Anchorage, AK 99518 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kevin Tabler Unocal PO Box 196247 Anchorage, AK 99519-6247 Dudley Platt D.A. Platt & Associates 9852 Little Diomede Cr. Eagle River, AK 99577 J Greg Noble Bureau of Land Management Energy and Minerals 6881 Abbott Loop Rd Anchorage, AK 99507 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Paul L. Craig Trading Bay Energy Corp 5432 East Northem Lights, Ste 610 Anchorage, AK 99508 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Mark Worcester ConocoPhillips Alaska, Inc. Legal Department A TO 2090 PO Box 100360 Anchorage, AK 99510-2090 Perry Markley Alyeska Pipeline Service Company Oil Movements Department 1835 So. Bragaw - MS 575 Anchorage, AK 99515 David Cusato 600 West 76th Ave., #508 Anchorage, AK 99518 Tesoro Alaska Company PO Box 196272 Anchorage, AK 99519 Sue Miller BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Bob Shavelson Cook Inlet Keeper PO Box 3269 Homer, AK 99603 ~ Jeff Walker US Minerals Management Service Regional Supervisor 949 East 36th Ave., Ste 308 Anchorage, AK 99508 Richard Prentki US Minerals Management Service 949 East 36th Ave., 3rd Floor Anchorage, AK 99508 Thomas R. Marshall, Jr. 1569 Birchwood Street Anchorage, AK 99508 Jim Ruud ConocoPhillips Alaska, Inc. Land Department PO Box 100360 Anchorage, AK 99510 Kristen Nelson IHS Energy PO Box 102278 Anchorage, AK 99510-2278 Robert Britch, PE Northem Consulting Group 2454 Telequana Dr. Anchorage, AK 99517 Bill Bocast PACE Local 8-369 clo BPX North Slope, Mailstop P-8 PO Box 196612 Anchorage, AK 99519 J. Brock Riddle Marathon Oil Company Land Department PO Box 196168 Anchorage, AK 99519-6168 BP Exploration (Alaska), Inc. Land Manager PO Box 196612 Anchorage, AK 99519-6612 Peter McKay 55441 Chinook Rd Kenai, AK 99611 Shannon Donnelly Phillips Alaska, Inc. HEST -Enviromental PO Box 66 Kenai. AK 99611 0 Kooo' P"'nsu~ Borough Economic Development Distr 14896 Kenai Spur Hwy #103A Kenai, AK 99611-7000 Marc Kovac PACE 8-369, Prudhoe Bay Vice-Chair PO Box 2973 Seward, AK .99664 James Gibbs PO Box 1597 Soldotna, AK 99669 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 John Tanigawa Evergreen Well Service Company PO Box 871845 Wasilla, AK 99687 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Cliff Burglin PO Box 131 Fairbanks, AK 99707 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow. AK 99723 Kurt Olson State of Alaska Staff to Senator Tom Wagoner State Capitol Rm 427 Juneau, AK 99801 Lt Governor Loren Leman State of Alaska PO Box 110015 Juneau, AK 99811-0015 ~ Penny Vadla Box 467 Ninilchik, AK 99639 Claire Caldes US Fish & Wildlife Service Kenai Refuge PO Box 2139 Soldotna, AK 99669 Charles Boddy Usibelli Coal Mine, Inc. 100 Cushman Street, Suite 210 Fairbanks, AK 99701-4659 Harry Bader State of Alaska Department of Natural Resources 3700 Airport Way Fairbanks, AK 99709 North Slope Borough PO Box 69 Barrow, AK 99723 (, ..-.. ~ Unocal Alaska Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519-6247 Telephone (907) 276-7600 UNOCAL(Ð "';;¡if_r- .. Alaska ~::(¡.~.C:.".¡.\..f.'i.:,..'.'.:O.r..... '.J clJ~~ '4 t..,,""""'" APR 0 ;7 ZO03 Kevin A. Tabler Land Manager April 1, 2003 Of¡ &. ~ Cons. Gcmm\sslon A_a . P\::e.::-::~Jj'a State of Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Commission Chair Sarah Palin Re: Storage Injection Order #3 Rule 7 Administrative Approval Kenai Gas Storage Facility #3 Swanson River Field Dear Chair Palin: In 200 1, Union Oil Company of California (Unocal) commenced operation of a gas storage pilot project within the boundaries of the Swanson River oil field. Unocal refers to this gas storage operation as the Kenai Gas Storage Facility. Unocal's gas storage project is intended to provide a certain stored volume of gas to meet peak rate requirements during seasonal high demand periods. The design is intended to put a large volume into a reservoir at relatively high injection rate and withdraw the gas at a relatively high rate during peak demand periods. On March 6, 2002, Union Oil Company of California (Unocal) filed with the Commission its Application for Injection Order for Storage Injection Well, Kenai Gas Storage Facility #2 (KGSF #2), and on June 5, 2002, the Commission approved Unocal's application and entered Storage Injection Order #3. Well KGSF #2 was originally planned as a redrill of SRU 212-27 with a 500' lateral in the Tyonek 62-5 sand - by letter dated March 25, 2002, Unocal requested well SRU KGSF #2 be a re-drill of existing well SRU #12-27 instead of well SRU #212-27. Unocal drilled KGSF#2 last summer but encountered a problem during completion which would tend to limit injectivity and/or productivity; thus, it remains shut-in pending further evaluation. Accordingly, pursuant to Rule 7, Storage Injection Order #3, Unocal hereby requests Commission approval to drill KGSF #3, a grass roots gas storage well with a horizontal completion in the Tyonek 62-5 Sand. Rule 7 authorizes the Commission to take Administrative Action as follows: Storage Injection Ordr3 Rule 7 Administrative Approval Kenai Gas Storage Facility #3 Swanson River Field Page 2 Upon request or its own volition, the Commission may administratively revise and reissue this order or any of its rules upon proper showing that the change is based on sound engineering and geoscience practices, will not allow stored fluids to escape from the injection zone, and will not cause waste. .~, v The drilling of KGSF #3 will provide an alternative delivery point for the storage of natural gas in the Tyonek 62-5 Sand, gas storage formation, and is reasonably necessary for Unocal to maximize storage potential. Cultural resources will not be affected by the proposed grass roots well because all work will be done from existing pads and roads. Additionally, there is no history of hydrogen sulfide in the Swanson River Field in any of the formations that this proposed well will encounter during drilling operations. Finally, KGSF #3 targets the same injection zone as KGSF #2 (Tyonek 62-5 Sand, gas storage formation), and thus, (as the Commission held in Storage Injection Order #3) the conclusions that applied to the drilling of KG SF #2 should also apply to the drilling of KG SF #3, as follows: 1) The project as described and proposed meets the requirements of 20 AAC 25.252. 2) The mechanical integrity of SRU KGSF #3 will be demonstrated according to the requirements of 20 AAC 25.252(d) prior to initiating gas injection and storage operations. 3) The proposed injection of natural gas into the SRU KGSF #3 well for the purpose of storage will not cause movement of hydrocarbons into sources of freshwater. The proposed storage of natural gas in SRU KGSF #3 will not cause fluids to move behind casing beyond the approved storage zone. 4) 5) The proposed storage of natural gas in well SRU KGSF #3 will not propagate fractures through the confining zones. 6) The proposed injection of natural gas into the SRU KGSF #3 well for the purpose of storage will not cause waste, jeopardize correlative rights, endanger freshwater, or impair ultimate recovery. 7) Surveillance of operating parameters on the storage well and offset wells will aid in preventing stored gas from moving out of the formation where it is intended to be stored. The proposed spud date for KGSF #3 is May 15,2003. Therefore, in accordance with Rule 7 of Storage Injection Order #3, Unocal respectfully requests the Commission's approval to drill KGSF #3 in order to provide Unocal with optionality with respect to injection and withdrawal of gas from the Tyonek 62-5 Sand, gas storage formation. Storage Injection ordlj Rule 7 Administrative Approval Kenai Gas Storage Facility #3 Swanson River Field Page 3 ,~ ~ If you have any questions in regards to this request, please call me at (907) 263-7600, or Mr. Jerry Bowen at (907) 263-7640. ~~ Kevin A. Tabler c $~fÆ~~ TI f fÆ~fÆ~~~fÆ c A I 1A.~1i& OIL AND GAS CONSERVATI ON COmnSSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7T" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 April 14,2003 Kevin A. Tabler Unocal Alaska Union Oil Company of California P.O. Box 196247 Anchorage, AI{ 99519-6247 Re: Application for approval to drill KGSF #3 Dear Mr. Tabler: Pursuant to 20 MC 25.252 (a), the Alaska Oil and Gas Conservation Commis- sion (" AOGCC" or "Commission") on June 5, 2002 issued Storage Injection Or- der No.3, authorizing Union Oil Company of California ("Unocal) to conduct underground storage of hydrocarbons by injection into the Tyonek Formation via the proposed Swanson River Unit ("SRU") KGSF #2 well. As a result of me- chanical difficulties in completing KGSF #2, Unocal subsequently requested Commission approval to drill and operate KGSF #3, a grass roots gas storage well with a horizontal completion in the Tyonek, in relatively close proximity to KGSF #2. Per 20 AAC 25.252 (g), AOGCC may, upon application, approve modifications of existing or pending disposal or storage operations under 20 MC 25.507. The latter regulation requires a submission to the Commission with an Application for Sundty Approvals (Form 10-403), when an alternate well is to be utilized for storage injection. AOGCC publicly noticed Unocal's intent to drill and operate KGSF #3 on April 11, 2003. Please submit to the Commission an Application for Permit to Drill (Form 10-401) for well KGSF #3. If KGSF #3 injection performance is satisfac- tory, then per 20 AAC 25.507, please submit a Form 10-403 modifying Storage Injection Order No.3 to authorize storage injection in KGSF #3. The Commis- sion may at that time require abandonment or operations shutdown of KGSF #2. Please be advised that AOGCC is not hereby authorizing expansion of Stor- age Injection Order No.3 to allow more than one operating well. ~ou fO~~~~ :;~, safah ~ ~t; sZunt, Jr. Chair Commissioner ~u~ Commissioner #10 JUN-06-2002 THU 01:22 PM U~AL ALASKA FAX NO. 90~63 7828 P. 01 Unocal Alaska 909 W. 9th Ave Anchorage, AK 99501 Mailing: P. O. Box 196247 Anchorage, Alaska 99519 Switchboard: (907) 276-7600 3n1 Floor Fax: (907) .~S3-7828 UNOCAL8 Fax Message: To: ffqv(( --- ,/kv;f'( Company: "... " r y (). r Compan~ Un~IAI~~ Fax: F~ 907~263-7e2e PhollMl= Phone: bate: t ~-c.. (i Z Pages: - Þages ~~IUdin9 Cover Sheet D Urgent 0 Fol' Rmew [J Plea.e Comment [J Ple..e Reply 0 PI.... Recycle " ..n - 'on. . Comments: stve 0 ~ "-It. . ,3.::~f :i'^ ~~ I '!~~?s- ~~Jo ;'1'~t .~I) ~Í'_IJ(I tc"", .$-(~(I~t--.~ H. (, /¡"Æ(--~?, ÁJd fY'I~y .ýJ~vJ Ia - - .I~ 1",:4" oM ,'[2 W. (.r, '1- ~~J M .tþ.,¡", £~ 5/Zl4 2-121).- , ..14 .If.¿;~(j ;1.- fP,(¡ ýr.~A ~(;+ !J~.f ,j"~,.,,lfft/ ,~.m~ 6£'k1L - .... - ~~ rt. kiT ---. -- fp. ~y ¡Jrr .. ..... - -.. . .. - . -- _u. . - . .-- -.. --. RECE I VE D JUN 0 6 2002 AII8ka Ci & Gas Coos. Commission , AndIoi. JUN-06-2002 THU 01:22 PM UNOCAL ALASKA ~ FAX NO. 90~63 7828 P, 02 Form 3160-5 (Juno 1990) UNr ,i) STATES ÐEPAR'1'MEN'f Opt ~HE INTERIOR SUREAU OF LAND MANAGEMEN'r FORM APPROVED Budget Burlll\u Na. 1004-0135 Explr~: March 31,1993 --- . _.. _u . S. I.easa peeignallan and SerIal No. SUNDRY NOTICES AND REPORTS ON WELLS Po not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use II ~PPLICA TION. ~OR PER~I" -"Jar such pro~()~als SUBMIT IN TRIPUC,ð,TE . ' 6. If Indian, A.aIIaO or Tribe Nama " - - ,-.. . 1.Type of wall - 011 .x. GaB ::- Oth~r 2. Name of Operator Unocal 3. Address and TelephQne No, . P.O. ßo~ .1.96247 Anoho~ge. AIQsk~ -~~~J ~47 4. LQQó\Uon of Won (Footage, Sec., T., R,. M.. or Survey Descñption) 7. If Unit Dr GA, AglQolnenl Doslgnallon Swanson River Unit 8. Willi Nama and No. SAU 212.27 9. API Well No. 6Q.133.10163-o0 10, FIeld and Pool, or ExploralOlY Are.'!. Swanson Riverl 11, county or Parish, Stat!¡ - ,'. - " . ~~I, Alaska .9_HECK APPAO'p':'~T~ BOX(s) TO INDI9ATe NATUAE OF NOTICE, AE~OAT., OR OTt!I;R.D~lA_. TYPE OF SU~~J.~.SION TYpe OF ACTION 0 'Ñ~li~ of Inlanl Œ1 AIIandonmenl 0 Chango of Plans 0 AeQQl11p1elÎon 0 New Can9lrUcdon 0 Plugging Sack 0 Nan-ADuline Fr¡u¡lIIrlng 0 Gasing t\øpaIr' 0 Wlltlll' Shl-Of' 0 Altering Casing 0 Conversion 10 Ihèctlon 0 01l111r remove lowerllðckar a.~!IV 0 Pispose WaIst (Nota: RBþott rooull:; of muiliplo cðmpIolion an Wen --__n... ... -, ,~omplollon or flecomplotion F\epo,rl~!,IQ "-Dg Iorm.) 13. D8$Çfibe Proposacl ar coMPloled Operal1ons (Cleluly "la,le all perlh1enl details, and give pertÎnÐnl datos.lnctucllng aalimatecl dele DI slarlinll iI/1~ pn¡pO$Ðd work. 11 wen Is dlrccdonally drlllltd, give 8ublillrlace IDeations and measured a/IIIlrue YBfUcai dOplhs lor In markers and zones pør1!nont to this work.) Abandon the e2.5 & 65-7 sands (Curret re$ElNoÎr pressure @ 931 psi) Set SchlumbergerThrough Tubing Poslset Plug @ 6210' Dump ball 1 0' of cement on top of plug Watt 24 Hours, Pressure test plug to 1500 psI. 12. rn SubSequent Report 0 Final Abandonment Nollea ;:';rforate the 61.30 sand @ 6076-6090' & 8104'~6108' with 1-11/16" Pivotgl..li'I RECE\VED JUN 0 6 2002 AIaIka Oil ¡ Gas Cons. QØÐi&iOn And\ðfagt DriUlnll Manaa&r - . . . .... Qa!e .:1" h. 3" () I /~¿ Tille. A¿¿.. p~a -*~ - -- , 11111110 U.S,c, Saotlon 1001, makes II Q CIlroo ror any po,.,," kf1oyvingly.1"I wlnr>Ji1y I. n'lake 10 Qny d"Pa~,""r¡I å' agency arllle U~ecI SlDI"" of?! ¡.\cIa, lJa1þlaUII or lraudlllsnlelnlam8nlO DT rap¡aaenl~lI~n~ ~.Io ony malu,r llvilhll'l \~ IlKllrdlcllOl\, . ..... - . #9 r---. 1 2 3 4 5 6 7 8 9 10 11 12 13 r-- 14 15 16 17 18 19 20 21 22 23 24 25 r-- ;-.. ,~ ALASKA OIL AND GAS CONSERVATION COMMISSION PUBLIC HEARING In Re: Swanson River Field - Application for Injection Order for Gas Storage Well, Kenai Gas Storage Facility #2. TRANSCRIPT OF PROCEEDINGS Anchorage, Alaska April 30, 2002 9:00 o'clock a.m. COMMISSIONERS: CAMMY OECHSLI TAYLOR, Chairperson DAN SEAMOUNT * * * * * * f",\ ".,,"'" ',"- ä \, f ... f'\ ~-( t: t, ì:: ! V l: LI !) n ')nn? ,., u ..., " "J<- Alaska OB 8. G<\~~ i),:m; LominissíOl Am:horaO8 METRO COURT REPORTING, INc. 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ,~ 1 2 3 4 5 6 7 8 9 10 11 12 13 ~. 14 15 16 17 ~. --.., , ~ 2 PRO C E E DIN G S (On record) CHAIR TAYLOR: Good morning. We'll call this hearing to order. Today is Tuesday, April 30th, and the time is 9:00 o'clock. We're at the Oil and Gas Conservation Commission office at 333 West Seventh Avenue. The subject of today's hearing is Unocal's application for an injection order for underground storage of gas for a well named KGSF #2, Swanson River Field. I'd like to introduce myself and my fellow Commissioner, Dan Seamount. I'm Cammy Taylor. To my very far right is Julie Gonzales from Metro Court Reporting. This proceeding is being recorded and a transcript will be made. If Unocal or anybody else wishes a copy of that transcript, they may secure it directly from Metro Court Reporting. The notice for the public hearing was published in the Anchorage Daily News on March 22nd, 2002. We'll conduct these proceedings this morning according -- in accordance with 20 18 I'll ask that the applicant present testimony MC 25.540. 19 first, and after that testimony if there's anybody else in the 20 audience, and it doesn't look like it at this point, who 21 wishes to present testimony, they may do so also. We ask that 22 when you are presenting testimony that you first be sworn in 23 and present your full name and spell it for the record, so 24 that the court reporter can make sure and transcribe that. If 25 there are any other members who -- of the public or of any METRO COURT REPORTING, INC 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ;-', 1 2 3 4 5 6 7 8 9 10 11 12 13 r-.. 14 15 16 17 18 19 20 21 22 23 24 25 ...--~ ,-- ~ 3 other group who may appearl weIll allow them an opportunity to testifYI or if they have comments weIll allow them to make comments after you present testimony. Who is going to be representing Unocal for us? MR. MARTIN: 1/11 go ahead and just briefly start off with a little bit of an introduction and then..... CHAIR TAYLOR: Why don/t you step forward to the microphone thenl so that we can make sure and pick that all up. MR. MARTIN: shannon Martin for Unocal. CHAIR TAYLOR: Shannon I do you wish to be sworn? Are you going to present testimony or are you just going to present. . . . . MR. MARTIN: I think 1/11 just go ahead and give a brief introductionl nothing that needs to be sworn. CHAIR TAYLOR: Okay. MR. MARTIN: Good morning I Commissioners. ObviouslYI the purpose we/re here is to prevent test- -- present testimony. Unocal has entered into negotiations with the BLM to enter into a gas storage agreement at the Swanson River Field. This is an extension of our pilot program we began last fall with the 4328 well. And essentially the gas storage agreement is for the purpose of storing gasl whether or not from federally owned lands in the Tyonek formation. The purpose of the agreement is two-fold, to meet the laws of METRO COURT REPORTING, INc. 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 r--, 5 6 7 8 9 10 11 12 13 /"-'. 14 15 16 17 18 19 20 21 22 23 24 25 /--~ .,~ ~ 4 1 supply and demand really. Unocal is a pioneer with gas 2 storage in Alaska. We believe this is a very successful 3 program. 4 Gas storage enables Unocal to meet its commitments to Enstar and to Agrium (ph). It's a method to avoid undue economic waste, it enables Unocal to avoid shutting in wells in summer months to the extent that it has met its production demands, and enables Unocal to meet its high peak demands in winter months by looking to a surplus that's at gas storage at Swanson River. In order to address your questions we received some issues yesterday from Mr. Steve Davies, alluding to some engineering geology questions that you had concerning gas storage and cementing of the container, questions of waste, et cetera, and we would like to speak to those issues. So I'll sort of give you the board now to ask us the questions as you deem necessary. Erik, would you like to sort of just kind of layout the container from the structure contour map perspective? You know, where we intend to store gas in the Tyonek formation and why we feel the container is where we think it is with regard to the existing participating area? MR. GRAVEN: Yeah, I can do that. MR. MARTIN: Would that be something that..... CHAIR TAYLOR: That would be great. Erik, if you wouldn't mind coming up here, then the microphone can pick you METRO COURT REPORTING, INc. 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 r-, 3 4 5 6 7 8 9 10 11 12 13 r--, 14 15 16 17 18 19 20 21 22 23 24 25 ",--,.., --- -- 5 1 Do you wish to be sworn as an expert witness? up. 2 Yeah, you should. MR. MARTIN: CHAIR TAYLOR: Why don't I swear you In first, and then if you would briefly state what your qualifications are for the record. Would you raise your right hand. (Oath administered) MR. GRAVEN: Yes, I do. CHAIR TAYLOR: If you would state your name and spell your last name for the record so that the court reporter has that. MR. GRAVEN: Yes, Erik Graven, last name G-r-a, V as in Victor, e-n. And I've been a geologist with Unocal for nearly 12 years now. I have a Masters of Science degree from Oregon State. I guess that's about the extent of my experience. CHAIR TAYLOR: Mr. Seamount, do you have any questions about his qualifications? COMMISSIONER SEAMOUNT: I have no questions, nor any objections to him being an expert. CHAIR TAYLOR: We'll qualify you as an expert witness for the purpose of your testimony today. MR. GRAVEN: I did not bring any large exhibits, so I'd like to just talk off the map that was provided in the application. The sand that we're proposing storage in is what Unocal calls the 62-5 sand in the Tyonek formation. The top METRO COURT REPORTING, INC 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ,"'--' 1 2 3 4 5 6 7 8 9 10 11 12 13 ,------, 14 15 16 17 18 19 20 21 22 23 24 25 ,"--'" ~ ,-.., 6 of this sand is at roughly 6/045 feet subsea in the area that we/re planning injection. This structure map is from the central part of the Swanson River Fieldl andl let/s seel the well that we are proposing to sidetrack and drill a horizontal into this sand from is the 12-27 well. In the original application we had proposed at 212-27. For various reasons we/re not going to be using that weIll we/re going to be using the 12-27 sidetrack. And we will be drilling that well to the southwest from the 12-27 location. So that will be in the kind of northern edge of this accumulation as its shown on this map. The gas accumulation on this map is denoted by the crosshatch pattern on the map. Now I don/t know if you want me to go into any of the questions that were brought up regarding this at this point I or.... . COMMISSIONER SEAMOUNT: If you feel it would help to go into theml go ahead. If notl we can ask them. MR. GRAVEN: I know one of the main issues was the permeability barriers. And one of the questions I believe was what is the nature of these barriers. And to tell you the truthl we don/t now what the nature of them is. We/ve put them in based on our belief that some of the wells that are still structurally highl that should have gas in theml appear to be wet. So it appears that there is some kind of barrier between the wells where we know there is gasl 12-271 212-271 METRO COURT REPORTING, INc. 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ,~ 1 2 3 4 5 6 7 8 9 10 11 12 13 /---, 14 15 16 17 18 19 20 21 22 23 24 25 ~ ,~ ,-, 7 and these wells that appear to be wet, such as SRU21-27 and SRU314-27. COMMISSIONER SEAMOUNT: Where is the three four- -- oh, okay. MR. GRAVEN: That is the well that's drilled off to the south and there's a cross just south of that permeability barrier, yeah. COMMISSIONER SEAMOUNT: Now did that well -- you say it appears to be wet. What was the evidence it was wet? MR. GRAVEN: That well, 314-27, has very low resistivities. I don't have that log with me, but they are on the order of five ohm (ph) meters in the upper part of the sand. The lowermost had higher resistivities, but the upper part where there should be gas it appeared very low resistivities. We had no porosity logs on that well one. COMMISSIONER SEAMOUNT: What would be a typical producing resistivity? MR. GRAVEN: 12-27 and 212-27 are in the order of 10 to 11 ohm meters. Let me correct that, nine to 12 ohm meters. COMMISSIONER SEAMOUNT: Have you ever tested a low resistivity sand in this -- for an equivalent low resistivity sand to the 65 -- at 62-5? MR. GRAVEN: Not equivalent stratigraphically to the sand. We have tested Tyonek sands that have been as low as six ohm meters and have produced gas. METRO COURT REPORTING, INc. 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 /"", . r--,- .~ ",-, .....-.. 8 1 COMMISSIONER SEAMOUNT: Okay, but..... 2 MR. GRAVEN: But we don't have offsetting well 3 information to know what the water saturation is in that sand. 4 COMMISSIONER SEAMOUNT: from a Tyonek test? MR. GRAVEN: Yes. COMMISSIONER SEAMOUNT: Have you ever recovered water 5 6 7 And what. . . . . 8 MR. GRAVEN: We have recovered water from 9 resistivities up to 20 ohm meters. 10 COMMISSIONER SEAMOUNT: Okay. 11 MR. GRAVEN: The water resistivity varies quite a bit 12 from sand to sand across the field and vertically 13 stratigraphically. I did run some basic water saturations on 14 a number of these wells, and in the wells where we believe the 15 gas cap is present, those water saturations are generally 16 coming out to be around 55 percent. I want to qualify those 17 numbers, they're probably more qualitative than quantitative. 18 Since we don't have a good handle on RW, I made an estimate of 19 what I thought it might be. But just for comparison purposes, 20 I used the same RW in all the wells. And again, in the gas 21 cap it's around 55 percent. In the 21-27 well, it was running 22 about 65 percent. So that is the reason we thought that well 23 It did have a higher water saturation than the other was wet. 24 wells. 25 COMMISSIONER SEAMOUNT: Do you have any porosity logs METRO COURT REPORTING, INC 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ,/""'. ~, '----'" r--." ~ 9 1 other than sonic through this interval? 2 No, we do not. MR. GRAVEN: 3 How do you calculate porosity COMMISSIONER SEAMOUNT: 4 from the sonic? 5 We use an in-house transform we'd like to MR. GRAVEN: 6 keep confidential, but if -- I could give it to you, but it 7 incorporates a compaction factor. I don't know how else to 8 describe it. 9 COMMISSIONER SEAMOUNT: Does it -- have you..... 10 MR. GRAVEN: It's based on empirical evidence from 11 Cook Inlet. 12 COMMISSIONER SEAMOUNT: Okay. Are there any cores 13 from this interval that you've calibrated it with? 14 No, we do not have any core. MR. GRAVEN: 15 COMMISSIONER SEAMOUNT: Okay. What about the cap 16 rock? What's the characteristic of the cap rock? 17 MR. GRAVEN: If I remember, there was a 13 foot I'd 18 call a mudstone overlying our target interval. And then there 19 is another 10 foot thick -- 10 to 12 foot thick coal overlying 20 that mudstone. 21 Does this cap rock appear to COMMISSIONER SEAMOUNT: 22 be extensive through the area? 23 MR. GRAVEN: Yes, it does. 24 Is there any reason why it may COMMISSIONER SEAMOUNT: 25 have fractured or cracked during production of the sand? METRO COURT REPORTING, INc. 745 West Fourlh Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ~ 1 2 3 4 5 6 7 8 9 10 /-~, MR. GRAVEN: ~ 10 I can't think of any reason, no. COMMISSIONER SEAMOUNT: I don't think I have any other geology questions. engineering? MR. GRAVEN: Are you going to be presenting some We certainly can. Okay. Well, we have some COMMISSIONER SEAMOUNT: questions of Mr. Orr. MR. GRAVEN: CHAIR TAYLOR: as an expert witness? 11 12 13 please? ~ 14 15 16 17 18 19 20 21 22 23 24 25 ~ MR. ORR: CHAIR TAYLOR: Thank you, Mr. Graven. You're welcome. Mr. Orr, do you also wish to be sworn Yes, I do. Would you raise your right hand, (Oath administered) MR. ORR: CHAIR TAYLOR: as an expert. O-r-r. MR. ORR: Yes, I do. If you would state your qualifications I have worked in the oil and gas industry for 13 Yes, I -- my name is Gary Orr, last name is years, nine of them with Unocal. I've got a Bachelor of Science from Penn State University in petroleum and natural gas engineering. or.... . CHAIR TAYLOR: Mr. Seamount, do you have any questions COMMISSIONER SEAMOUNT: No questions, nor do I object. METRO COURT REPORTING, INc. 745 West FoUlth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ~ ~" "r---. .~ ~ 11 1 CHAIR TAYLOR: We'll consider you an expert for 2 purposes of your testimony today. 3 COMMISSIONER SEAMOUNT: Would you like to make any 4 statements or should we go right to the questions? 5 MR. ORR: Let's go right to questions. 6 COMMISSIONER SEAMOUNT: Okay. Storage injection order 7 number two concerned 43-28 well. How did -- have you injected 8 into that well yet? 9 MR. ORR: Yes, we have. 10 COMMISSIONER SEAMOUNT: And how did it behave? 11 MR. ORR: It behaved as we'd predicted on our P over Z 12 We got P production out of it this winter of around 10 curve. 13 million a day, and because of the mild conditions we had this 14 winter we've actually got the well fairly full right now. 15 COMMISSIONER SEAMOUNT: And are you keeping it under 16 original reservoir pressures? 17 MR. ORR: Yes, we are. 18 COMMISSIONER SEAMOUNT: And the injection is in a 19 different sand, is that right? 20 MR. ORR: That's correct. 21 COMMISSIONER SEAMOUNT: Okay. There was concern about 22 well 21-27, the well that Mr. Graven described as being across 23 the permeability barrier, but containing some sand that looks 24 like it's in the equivalent interval. And the concern was it 25 doesn't look like cement is across that sand. Is that METRO COURT REPORTING, INc. 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ~ 1 2 3 4 5 6 7 8 9 10 11 12 13 r--. 14 15 16 17 18 19 20 21 22 23 24 25 ~ /~ ~ 12 correct? MR. ORR: That's correct. And the bond log that we have clearly shows that there is not cement across that sand. COMMISSIONER SEAMOUNT: Is there a way to monitor that well while you're doing injection in case there is some sort of breach into that sand and -- during your operations? MR. ORR: We can monitor the casing annulus pressure. COMMISSIONER SEAMOUNT: Okay. And through that monitoring you could tell if there was a problem with that well, is that correct? MR. ORR: Yeah, if we had gas that came into the annulus and pressure up the backside, yes, we could tell. COMMISSIONER SEAMOUNT: Okay. In your prefiled testimony you talk about maximum injection pressures, maximum rates. What would be your maximum intended reservoir pressure when you have full storage? MR. ORR: The original reservoir pressure in the 62-5 sand is estimated to be 2,716 psi before we depleted it, and we would not exceed that number. COMMISSIONER SEAMOUNT: And what would be the maximum rate that -- what would be the maximum volume of gas that you would store in this reservoir? MR. ORR: The depletion that we've had in the reservoir has just shy of two BCF, and it would be our intent to try to fill it up as close to that two BCF as we could get. METRO COURT REPORTING, INc. 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 .~, ,r--'. .,~, /----, ,..--..... 13 1 COMMISSIONER SEAMOUNT: And what would be the 2 cumulative -- or the maximum production out of the two storage 3 wells during -- what would it be during the winter? 4 MR. ORR: We would -- we'd deplete them as much as we 5 needed, depending on the winter. We calculated that our rate 6 is going to be about 10 million per day from each one 7 initially. We know from this one here that we were not able 8 to economically -- we weren't able to flow the well beyond 9 once we got just shy of two BCF, and therefore we would not be 10 able to get any more than that out of the well. 11 COMMISSIONER SEAMOUNT: Okay. Do you have any future 12 plans for other injection orders in this area? 13 MR. ORR: Yes, we do. 14 COMMISSIONER SEAMOUNT: And would you know when those 15 would be coming up? 16 MR. ORR: We actually have had on our budget this year 17 for a third one into the Sterling sand in the far north part 18 of the field. Due to budget constraints, we dropped that 19 project off. It may be next year, it may be two or three 20 years from now. 21 COMMISSIONER SEAMOUNT: What kind of storage would 22 that Sterling well have, as far as total gas? 23 MR. ORR: I don't have that information with me, but 24 it's in the same order as what we're looking here on this 25 reservoir. METRO COURT REPORTING, INc. 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 .r--', ,'--- .----" "--"", 14 1 Okay. And was that the same COMMISSIONER SEAMOUNT: 2 for the 43-28, about two BCF? 3 I think it was a little bit smaller. It was MR. ORR: 4 closer to a BCF and a half. 5 Okay. That's all the COMMISSIONER SEAMOUNT: 6 questions I have for you, Mr. Orr. Thank you very much. 7 CHAIR TAYLOR: Do you have anything else that you'd 8 like to add to that? 9 Well, again, gas storage allows Unocal to MR. MARTIN: 10 meet its peak demands by ensuring that the seasonal supply 11 exceeds the demand. There are no issues of native gas, this 12 is all produced gas. Whether or not from federally owned 13 land, it's being injected and withdrawn. Thank you to the 14 Commission for calling us here. 15 Oh, you're very welcome. We were just CHAIR TAYLOR: 16 going to ask if you would mind if we took just a quick break 17 and then we can come back with any additional questions before 18 we close the record. 19 MR. MARTIN: Great. 20 Okay. Off record. CHAIR TAYLOR: 21 (Off record) 22 (On record) 23 The time is approximately 9:35. Thank CHAIR TAYLOR: 24 you for accommodating our break. I think Mr. Seamount has 25 just one more question. METRO COURT REPORTING, INc. 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 r--' 1 2 3 4 5 6 7 8 9 10 11 12 13 r-- 14 15 16 17 18 19 20 21 22 23 24 25 --" ~ '---"'\ 15 COMMISSIONER SEAMOUNT: I have two more questions. CHAIR TAYLOR: Two more, sorry. COMMISSIONER SEAMOUNT: First of all, Mr. Graven, you stated that side -- that the redrill was going to go southwest. And I have Attachment 2 and Attachment 3 where it appears like it's going northwest. Am I reading -- or..... MR. GRAVEN: Yes. COMMISSIONER SEAMOUNT: . . . . . north. Am I reading this wrong? MR. GRAVEN: Well, did we provide updated attachments? MR. ORR: No, we did not. MR. GRAVEN: Okay. No, you're reading that correctly. Our current plan is to redrill from the 12-27 well instead of the 212-27, and then try to stay close to the 212-27 well. So as a result, we'll be drilling it to the southwest. COMMISSIONER SEAMOUNT: Okay. Could you provide the Commission with updated Attachment 2 and Attachment 3? MR. GRAVEN: Do we have those? Do you have Sure. those with you? MR. ORR: Not with us, no. MR. GRAVEN: Oh, you have other attachments, though, right? MR. ORR: I mean, there was a -- there was a Yes. question -- a list of questions we were given. We were -- one of them was a needed equivalent displays to Attachment 12 and METRO COURT REPORTING, INc. 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ,~ 8 9 10 11 12 13 ,"'---" 14 15 16 17 18 19 20 21 22 23 24 25 r---, /~ r', 16 1 13 for 212-27 and 21-27. I brought those attachments with me. 2 Would you like to submit those to be CHAIR TAYLOR: 3 part of the record? 4 MR. ORR: Yes. 5 CHAIR TAYLOR: Okay. 6 We'll supply the updated attachments as MR. MARTIN: 7 well. CHAIR TAYLOR: How long do you think it will take to get those? MR. MARTIN: Oh, we can do that today, can't we? We can get those today or tomorrow? CHAIR TAYLOR: Thank you. MR. MARTIN: Yeah, today or tomorrow. CHAIR TAYLOR: How about if we keep the record open then until tomorrow at 4:30 in order to accommodate that. Do you have a question? COMMISSIONER SEAMOUNT: And I had one other question for Mr. Orr. How often do you plan to monitor the offset wells? MR. ORR: We do that now when the operators make their rounds. I believe we do it daily. COMMISSIONER SEAMOUNT: Okay. And would that include the 21-27? MR. ORR: Yes, it would. COMMISSIONER SEAMOUNT: Okay. And is that well -- METRO COURT REPORTING, INc. 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ~. 1 2 3 4 5 6 7 8 9 10 11 12 13 ~ 14 15 16 17 18 19 20 21 22 23 24 25 ~ ~. ~ 17 that well is not abandoned, is that correct? MR. ORR: No, it's currently a Hemlock producer. COMMISSIONER SEAMOUNT: Oh, okay. It looks like on your map it's an abandoned oil well. MR. MARTIN: That's probably an error. Definitely an error. COMMISSIONER SEAMOUNT: Okay, thank you. I have no further questions. CHAIR TAYLOR: Okay. Well, for the purposes of the record, we're going to incorporate by reference all of the Commission well history file and well history data for the SRU well 21-27, the 212-27, the 12-27, the 314-27, and the 43-28. And that will be part of the record for purposes of this decision as well. Anything additional from us? COMMISSIONER SEAMOUNT: I have no further..... CHAIR TAYLOR: Any comments or additional information from Unocal? MR. MARTIN: No, thank you. CHAIR TAYLOR: All right. Thank you very much for the presentation and for all the information. And thank you for responding to the questions on short notice. MR. MARTIN: Thank you. (END OF PROCEEDINGS) * * * * * * METRO COURT REPORTING, INc. 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ,~,' r-- -----, ,/"'. r', 18 1 C E R T I F I CAT E 2 ) ) ss. ) SUPERIOR COURT 3 STATE OF ALASKA 4 I, Cari-Ann Ketterling, Notary Public in and for the State of Alaska, do hereby certify: 5 6 THAT the foregoing pages numbered 02 through 17 contain a full, true and correct transcript of the Public Hearing before the Alaska Oil and Gas Conservation Commission, taken by Julie o. Gonzales and transcribed by Julie o. Gonzales; 7 8 9 THAT the Transcript has been prepared at the request of the Alaska Oil and Gas Conservation Commission, 333 West Seventh Avenue, Anchorage, Alaska. 10 DATED at Anchorage, Alaska this 20th day of May, 2002. 11 SIGNED AND CERTIFIED TO BY: 12 13 14 15 16 17 18 19 20 21 22 23 24 25 METRO COURT REPORTING, INc. 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 #8 --------- #7 r-- '--"\ 510 3 - 5RU #12-27 Questions I Concerns I Comments Waste (recoverability of injected gas): . Concern since this project is essentially driven by economics (hold gas until prices are higher during winter months). . Areal extent of receiving 62-5 sand "tank:" 1. Expected configuration (areal extent) injected gas. 2. Unocal interprets the 62-5 sand in the offset SRU 21-27 well is NOT connected to the correlative sand in SRU 12-27. Why? 3. What is nature of permeability barriers? How can they be confirmed? How can they be better located? Assurance injected gas will remain within the 62-5 sand: . Lithology, thickness and areal extent of "cap rock" claystone. . Proposed injection pressures must be conclusively demonstrated to NOT cause fracturing of the thin (13 foot) claystone that separates the 62-5 sand from 51 feet of overlying, water-bearing sand. Safety Concerns: . Assurance of integrity of offset wells: confirmation that offset wells: a. do not intersect the injection zone, or b. if they do intersect the injection zone, it is covered by adequate cement. . Cement across corresponding sands in nearby well SRU #21-27 is a concern . 7" production casing was run from surface to 11,142', and cemented with 2,200 sacks. Cement was found in the casing at 9358 and cleaned out to 11000'. CBL shows top of good cement at 9000', or about 2700' below the proposed injection interval. #6 ,~ ,- STATE OF ALASKA OIL AND GAS CONSERV A TION COMMISSION SWANSON RIVER FIELD STORAGE INJECTION APRIL 30, 2002 9:00 AM NAME - AFFILIATION ADDRESS/PHONE NUMBER TESTIFY (Yes or No) (PLEASE PRINT) N6 ~ tú- r í-f.-.A 7 A'ot;cc. 7' ., ~/2 1"2.- m;;w:- ,$ t, -. 11~ ~HI\ f4JII)tL 7f1W" 6-n~/oÞ-Þ- lAN~ul1- ~3 - J¡,çJ' (fIN- () Ml4Irt.:r U J - 7 '13) ~ Ii. ~<b"- !~ - V<: v,:,-' ~ V ,¿~ A ú r-7d3 /2,-']</ '-0 ? C -no- 7. - .. ¿ #5 . . , , . f r UNOCALe AIa8ka Oil It Gas CO1II. Coom\isSiOn At.~ CASING AND TUBING DETAIL GRADE CONN TOP Surf Surf Buttress Surf (~ RECEIVED APR 3 {) I RKB to TBG Head = 14.32' Tree connection: TC-3 Un i-bolt "'---../" 1 ~3;1 j:I'I~¡I~ r~ i .DV@ 4430' L Top of Fill 7609' 10/1/88 - . ~ SIZE WT 22" 9-518" 40 5-1/2" 17 2 .~ -~ f . SwRlson River Field We. . # SRU 212-27 Ac~Jal Completion, 11/24/96 ~ J-55 N-80 BOTTOM 32' 3455' 7800' ~ Tubing String: 2-3/8" 4.6 N-80 Buttress Surf with 3/8" SS methanol injection line Surf 5878' 2508' JEWELRY DETAIL Depth Item 14.32 2-3/8" Tbg hgr wI Cameron H BPV profile 2508 Macco 2-3/8" SMa-lCI Chern Inj Meld wllOOO psi chem inj valve Maceo 2-3/8" D-SO glm w/l" dummy Baker "FH Retr. pkr, 2-3/8" x 5-112" 17# X nipple Tubing tail (shear out sub) Tubing Cut, 10/27/96 Cameo MM mandrel with CEV Tubing cut, 10/25/96 2-3/8" Baker bridge plug, 10125/96 Cameo D nipple . Baker D packer Bottom of tubing tail PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS ~ 3 NO. 1 2 TOC@ 5800' a:::;:;. ~m CBL 10/2/61iJ& .~ . .:Ii~"...~ , OLæ ,.~, j¥~j: L-J ~~~þg 1~t\\~ ' 7135' -annulus ::t:t:t J, ' i ~~ Ill! . 7135' tbg }M!: "~'r~:~'" 4 3 5 4 6 I 5 /.,~' ~-It)¿'J , 6 ..""'- Jò\. '^"""If. # s "~"< A~ .,." 7 65-2'1-453-'1 5748 5799 5844 5878 7 Fish = 27' 8 8 of peñ gun 9 9a 10 11 12 6800 7544 7577 7582 7589 7601 7612 9 9a 10 11 12 ~ i" ~ ~ 6527 6537 7620 7625 7620 7635 ,-- ., 77"'1"1< 2/rz/¡.1- Pr. fed 2-!tJJ7 ~ .J-.lI¡ I ,. , 1961 WSO sqzd '61 1961 Prop abdn '96 4 L Tyonek 5 4 2890 2890 surf casing 3018 3028 surf casing 3152 3162 surf casing 3342 3352 surf casing ¿ f (¡ 4-1 b't ð ,/"Jt... {(j7~ tôc,o 1\ ~ PBTD = 7750' TD = 7800' MAX HOLE ANGLE = Straight 5C27 AC.DOC 4 Sqzd '61 4 Sqzd'61 4 Sqzd'61 4 Sqzd '61 v{ ~ r' ¡.t'/j¡ " "~. . . 1° " p"'n 11( I,H.r, '1\ /rtAj t( (t 1\, .? .,., P' . rr"H ¡I\U'.tv <..Y2 REVI~: 2128197 " " l{ ~ f J- (- iI((( (/,'; !tRAf..~~~~:t: ~~ ,,( " S1N. Ç'tj¿ 1t1' Ç'¡'-2 r--- -- <. .' \ \. COMPLETION REPORT SWANSON RIVER UNIT 212-27 SECTION 27, T. 8 N., R. 9 t-l., SEWARD B & M STANDARD OIL CO. OF CALIFORNIA, W.O.I. - OJ?EPATOR Page 14. September 30, 1961 Ran Sch1umberger Induction-E1ectrica110g, the interva17799 - 3698', Sonic log 7797 - 3450' and Micro log 7798 - 6798'. Circulated and conditioned mud for ~"casing. laid down 4l11 drill pipe. Started running ~II casing. October 1, 1961 98 pcf mud Ran 183 Jnts. of 5t1l casing. Cemented 5i" casing at 7800' in two stages. with 1100 sacks of cement treated wi th O. 3oJo HR-4 using Halti burton power equipment. Used 1 top and 1 bottom rubber plug. 1st Stage around shoe with 600 sacks of cement. Pumped 30 bbls. of: water ahead, mixed 600 sacks of cement in 20 mins. using Halliburton truck, dis- placed in 16 mins. using rig pumps. Average slurry weight 116#. Bumped plug with 2000 psi. Full circulation. 2nd Stage through DV at 4430'. Dropped DV bomb, opened DV ports in 17 mins. Pumped 30 bbls. of water ahead, mixed 500 sacks of cement in 16 mins. using Halliburton truck, displaced in 9 mins. using rig pumps. Average slurry weight II6://:. Closed DV ports with 200 psi. Full circulation. Cement in place at 3:25 A.M. Hookload weight of: casing before cementing 103,000#, and af:ter cementing bef:ore land.i~g casing 104,00011. CASING DETAIL: Top 104 joints or 4,447.05' ~tI 17# 8 R DV Collar at 4,430' ~tI 17# 8 R Next 71 joints 3,048.46' Marker Joint 12.95' 7 joints 308.61' ~II 17# 8 R 7,817.07' Above K.B. 17.07' Casing cemented at 7,800.' Removed BOPE. Landed 5i1l casing. Installed tubing head. Reinstalled BOPE. Tested secondary pack-of:ts with 3500# psi and BOPE with 1800# psi. Drilled out DV at 4430'. r---. --- .... , \.1 COMPIETION REPORT SWÄNSON RIVER UNIT 212-27 SECTION 27, T. 8 N., R. 9 W., SEWARD B & M STAIIDARD OIL CO. OF CÄLIFORNIA, W.O.I. - OPEPATOR Page 15. October 2 and 3, 1961 Tested DV with 2000# psi, OK. Tested pipe rams and ,Kelly Cock with 2000# psi for 30 mins., OK. Drilled out Baffle Plate at 7709' and cleaned out cement to 7750'. Circulated and conditioned mud. Ran Schlumberger Neutron Collar log the interval 7752 - 7200' and Cement Bond log 7752 - 2200'. Perforated 5 ~II holes at 1620' for HCT#l. Halliburton casing test :/15 on 5 i-II holes at 7620'. Tool Assembly: 2 outside BT Recorders, 3' of' 2 7/811 perf'd. tail pipe, 5~" Hookwall packer, VR safety joint, hydraulic jars, 2 inside BT Recorders, bydrospring tester, and dual closed-in valves. Used no water cushion. Run on 7556' of 2 7/811 EVE tubing. Set packer at 7580' with 161 of' tail to 7596'. Opened tester for 4 mins. Initial Flow at 10: 53 P.M., dead. Closed tester for 30 min. Initial Shut-in Pressure at 10:51 P.M. Opened tester for 35 mins. Flow Test at 11:27 P.M., dead for 23 mins. (till 11:50 P.M.) then immediate strong blow with tubing pressure increasing to 2800 psi by 11:53 P.M. (approxi- mately 3 mine.). Tubing pin and Chicksan joints began leaking. Closed wing valves and pulled packer loose at 12:02 A.M. to kill well. Annulus mud began bubbling gas slightly. Started to bleed down tubing at 12:20 A.M. and pulled tubing (started pulling at 1:00 A.M.). Recovered 140' net rise, all drilling fluid testing 0.95 ohm at 500 F. or 75 G/G. Ditch tested 0.91 ohms at 650 F. or 100 G/G. PRESSURE RECORDER DATA: (Final Pressures) Depth' Gauge IR Top Inside Bottom Inside Top Outside Bottom Outside 7566 . 7570 7590 7594 5076 ISI IF FF FSI FR 29 29 29 5062 37 37 4.0 49 . 49 50 46 46 50 ~ VlSO. Circulated and conditioned mud. Built up mud weight from 97# to 100# pcf. Laid down 2 1/8" drill pipe. Started picking up 2 3/8" tubing. October 4, 1961. Picked up 2 3/8" tubing. Circulated. Perforated 4 ~" holes/foot the interval 7625 -' 7635'. Set Model "D" Packer, ran on Schlumberger line at 1600'. Ran in with 2 3/8" tubing as follows: ,'----" " .' ; ! ;i ; COMPLETION REPORT SWANSON RIVER UNIT ~J.2-27 SECTION 27, T. 8 N; L R,. 9 w. J. .BEt-lARD B & M . S~NDARD OIL CO. OF CALIFORNIA, W.O.I. - OPERA.TOR August 20, 1961 Spudded at 8:30 P.M. Drilled l2t" hole 0 - 3181 August 21, 1961 Drilled 12k" hole 318 - 2,1261 August 22, 1961 Drilled 12t" hole 2, 126 - 3,0001 Drilled 8 3/4" hole 3,000 - 3,5751 August 23, 1961 Drilled 8 3/4u hole 3,575 - 3,700 f Opened 12t" hole to 17k" hole 0 - 1,6001 3181 drilled 1,808' drilled 874' drilled 575' drilled 125 1 drilled 1,6001 opened --- \~ Page 3. 86 pci' mud 92 pci' mud Ran in 'With open end drill pipe and circulated. Ran Schlumberger I-ES log over interval 3700 - 100'; Sonic log 3694 - 1001; and Micro log 3698 - 24001. 88 pet' mud August 24, 1961 Reamed 12t" hole 1,600 - 3,0001 Opened 8 3/4" hole to 12t" hole 3,000 - 3,095' 1,4001 reamed 951 opened 86 pet' mud .r- ,,-.. " \., ,I . . COMPLETION REPORT SWANSON RIVER UNIT 212-27 SECTION 27, T. 8 N., R. 9 1/., SEWARD B & M STANDARD OIL CO. O~ CALIFORNIA, W.O.I. - OPERATOR Page 4. August 25, 1961 Opened 8 3/4" hole to 12t" 3,095 - 3,465' 3701 opened Ran 87 joints 9 5/8" casing. Cemented 9 5/8" casing at 34551 in 2 stages 'With 1620 sacks of cement using Halliburton power. equipment. Used 1 top plug. First Stage around shoe With 380 sacks of cement. Pumped 25 bbls. of water ahead, mixed 380 sacks of cement in 17 mins. using Halliburton truck, displaced in 25 mins. using rig :pum,ps. Average slurry weight 1181/. Bumped :plug With 2000 :psi. Full circulation. Second Stage through DV at 15321. Dropped DV bomb, opened DV ports in 15 mins. Pum.Ped 50 bbls. of water ahead, mixed 1240 sacks of cement in 38 mins. using Halliburton truck, displaced in 13 mins. using rig pumps. Average slurry weight 118#. Closed DV ports 'With 2000 psi. Full circulation. Cement in place at 8: 30 P.M. Hookload weight of casing before cementing 120,000#, and after cementing before landing casing 80,000#. CASING DETAIL: K. B. to landing head 38 joints 9 5/8" 40# 8 R - J-55 Top DV Collar DV Collar . 49 joints 9 5/8" 40# 8 R - J-55 including shoe and float collar Casing cemented at 15. 35 ' 1514.69' 1530.041 2.-,,1 1922.58' 3454.62' August 26, 1961 Installed and tested BOPE w/2000# psi, held OK. Ran in with 8 3/4" bit and drilled out DV and tested with 1650# psi, held OK. Tested Hydril with 1500# psi, held OK. Drilled out baffle plate at 33721 and cleaned out cement to 34001 . Ran Neutron Collar log over interval 3409 - 24091. Shot 4 i" jet holes per foot 2890 - 29001 for HCT #1. ',' ~,':' ' r-~ ~" >, ", ~'e;~,~~ ," r ; , ' " k', ." ~:: ~, ' f>~ " ~~), ~r"y, ~;~"" "}~' t t:' r, ~;;.. 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" "~ 9í . loiN' ,...--., kR I"" h'E 1. I. ~. ~ SHLl2/"O ' ".;?4SiNG tF-¡¡;8~~(;-iJ;TÄï~ ---,-_.. 1¿-.JI-G2 - - .IS' ~ !./f..""'~/ PI' . G J. 18'" , -Lvn~/1~ Vd"~~/-.6'5' -¿Pu,..,v'~.~~'7ü.h//7g-?85' ' -45 elk RJf8"lVÞ//?J;-N¿I./S' 11-'/(; -,7~ ,.: ~' " ., T~O ,cëh'). -i!.,¿ FJit¡ ~o~.¡., J/7ð -H~-I.85" ----;>-arme?Ø NAI Ñ.,nd'rf:t'/ Assci-m.6!!/ w/:th A1? ÁS--17- -IR.$O' ~c ~ /1';:' ; ¡ ~ . ~.feelts. R""'lûhl'hg-/4.5-1.GR' ~é'OO:?,SJ..' , C:~Q....~:!4 lIþ.rt .!,SJ/¿ <IS' ----:>-c?"'m~ H~ Hd"h'd~ Asst!'m.6(¿, /IV/tho Æ19 I~ ~ ~ /~O /' ~ ¡I€.O Ii, ~ r " , ~4/~ £~-/ú.6/hg-/R.!J.!1.6'9' , ," ,'. Or.J,., ¿...' :2...j~.,. " ~.! /,S1.44 --rQirh'?c:"O MJII HcVI'?CÝr#!'/ /lSSt!'h?h/g W/'/~ ..rv/ JúW'I... -- - PoOR' -.!/.!Jell's. £~.)Ú.6l'ng-/Q~dt.i'. . ~ ~ S¿>?é'.S<7' -rc?4I71C'O,uN A/dnQrf:t'1 As~4 W~;;q 1P¿11"'#/!,,: -#,05' -.;t7,,/rs ê~. 7úh/hg- ~7. 4-1' ~ , ' , G,J.?,,' ---:>-C'ö"A?t1O AlN Nó"nt:1'/-#!'/ ASSØhT..6I~ ...i/h RO Ycil/ne-/.!J.OO' , -2G.lIs..?~. 7i/h/hg--ai/. 6()" :,,' .~ ,Otl".ø; -raa/71«;,IÚI ÂhhC'nt'/ As.Seh'?ÞI§ wi/A- /PO ~/ye-I.:J.OO'. . -.?¿ ch'.t: t:? ~ ., Ñ./,6/h.9 -G$Ç..:J8' " -" ~ ""S..8r --rQ¡¡111C'O AIR .JMnQ/S/ A~.6& ~/A7 RO J'd/Þ'C' -/.1.0$' . . ' - ~ It/8#N' . .: h:l41lg~ K :IS I'IIs,Æ.ß" ,,'" , ,', .. , .' ',~~,,~. 'r"" , " ".:<;':i-;Þ<' , *,¡aa,.," ,....,>,..'" " ',6.4r, .. ,,-, -- -- .' .."'.'ij....:.r.'i",'i:,':i\;:;¡?--<"\:~(';XiH"j;lW¡t~-~~;'¡¡.,>"r¡"",".t;~'t'¡f-",., \,^;;' "'"':-"""'::'i<t","......,-~...."", - ' ... ~ i... ,~' \. COMPLETION REPORT SWANSON RIVER UNIT WELl ~TO~ ~1-27 SECTION 27 (Proj.) T. 8 L~., R. 9 ll. J s.r~W':.Rú B & M STANDARD OIL CO. OF CALÏFORNIÂ, W.O.I. - OPEFATOR April 3 - April 24, 1961 Drilled 9 7/8" hole 7,726 - 11,1421 T.D. April 25, 1961 Page 5. 3,416' drilled 97 - 98.5 pet mud Ran IES log to 11,142'. Started out with IES log and line pulled into keys eat at 3,0001. Worked line trying to get loose. Ran Bowen Socket on *" drill pipe over Sch1umberger line. Took hold of fish at ll,117'. Pulled loose, chained out. Recovered fish. Ran in and cleaned out 10,980 - 11,14.21. Cir- culated. 98.5 pcf mud A¡>ril 26, 1961 Ran IES log, interval 11,140 - 2,0361; Sonic log, interval U,134 - 2,036'; and Micro log, interval 11,140 - 9,4001. Circulated and conditioned mud. April ';If, 1961 98.5 pet mud Ran 264 joints ot 7" casing. CEMENTING DETAIL: Cemented 7" casing at 11,1421 in one stage 'With 2200 sacks of cement treated wi th 0.310 HR-4 using Halliburton power equipment." . Used one top and one bottom plug. Cemented around shoe With 2200 sacks of cement. Pumped 50 bbls. of water ahead, mixed 2200 sacks of cement in 40 mins. using Halliburton truck, displaced in 45 mins. using rig pumps. Average slurry weight 116:/1=. Did not bump plug. 2000 psi. Full circulation. CASING DETAIL: Top Next Next Next Next Bottom 4 22 88 42 43 65 264 ALL Landed casing at joints or 171.29' 7", 29#, P-ll0 BT joints or 931.22' 7", 26#, N-80 BT joints or 3,691.47' 7", 2?i#, N-80 BT joints or 1,800.19' T', 26:/1=, N-Bo BT joints or 1,814.97' 7", 29#, P-llO, BT joints or 2,74-4.171 7", 29#, P-IlO, 8 R joints or 11,153.31' Equipped with Baker shoe and Above K.B. 11. 31 ' collar one joint above. 11,14.2' . ., ',- ',,", " ~ ,.-.., '- '- COMPLETION REPORT SWANSON RIVER UNIT WELL i'IO. 21-27 SECTION 27 (proj.) T. 8 :~., R. 9 VI." SE:HARD B & M STANDAED OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR Page 6. April 28, 1961 Installed tubing head flange. Tested primary and secondary packoff to 3500 psi. OK. Installed and tested BOPE. OK. April 29, 1961 Located top of cement at 9,358'. Drilled, cleaned out cement 9,356 - 9,511'. AJ?ril 30, 1961 Drilled, cleaned out cement 9,511 - 10,125'. 96 pct' mud May 1, 1961 Drilled, cleaned out cement 10,125 - 11,000'. Ran Neutron Collar log, interval 10,980 - 9,980'. Jet perf'd. 5 - tIt holes at 10,672'. Prep. for WSO test. May 2, 1961 Ran WSO Test #1 on 5 - i" holes at 10,672'. WSO TEST: Tool assembly as follows: 2 outside BT recorders, 5' of 2 7/8" pert"d tail pipe, 7" type "C" hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorder, bydrospring tester, and dual closed in valve. Used 2,699' of W.C. Ran on 10,617', 2 7/8" drill pipe.. Set packer at 10,640' with 19' of tail to 10,659'. No ISI pressure. Opened tool to surface at 10: 26 AM for one hour flow test. Puff blow and dead. Shut in tool at 11:26 AM for 33 min. FBI pressure. Pulled packer loose at 11:59 A.'t. Recovered 40' net rise. All drill1ng fluid. PRESSURE DATA: IH IF FE' FBI FH Top inside 6991 1268 1268 1335 6991 Bottom inside 6952 1240 1240 1304 6952 Top outside 7061 1258 1258 1317 7061 Bottom oùtside 7050 1260 1260 1320 7050 Charts indicate tool open. WSO, OK. Ran Cement Bond log, interval 10,99° - 7,000'. Hemlock Zone. Good cement bonding through " . 0' ~ ,.-. '- '. COMPLETION REPORT SWANSON RIVER UNIT vlEIJ.. NO~21-:?7 SECTION 27 (Proj.) T. 8 N., Ro. 9 "¡., S:;:;W1l.PJ) B & M STANDARD OIL CO. OF cAriroRNlj.i., W.O.Y:-:-.ÕPEBATOR Page 3. March 18, 1961 Spudded at 2:00 PM 3-18-61. Drilled 16" hole 0 - 252' 75 pet mud 252' drilled March 19, 1961 Drilled 1611 hole 252 - 60' drilled 312' Drilled 1511 hole 312 - 2,035' 1,723' drilled Reamed hole 190 - 1,110' March 20, 1961 82 pet' mud Reamed hole 1,110 - 2,035'. . Circulated and conditioned mud. Ran 11 3/4" casing, casing stopped at 215'. P. O. casing. Ran in reamed hole to bottom. Made one more conditioning run. Circulated and conditioned mud. Ran 51 joints ot 11 3/411 casing. Landed casing at 2,029'. March 21, 1961 Cemented casing as tol1ows: CEMENTING DETAIL: Cemented 11 3/4" casing at 2,029' around shoe with 1350 sacks ot cement treated with O. ~ HR-4 using Halli bur'ton power equipment. Used one top and one bottom rubber plug. Pum,ped 50 bb1s. of water ahead, mixed 1350 sacks of cement in 50 mine. using Halliburton truck, displaced in 28 mins. using rig pumps. Average slurry weight 116#. Full circulation throughout and good returns. Cement in place at 8: 45 AM. CASING DEXAIL: 51 joints or 2,047.41' Above K.B. 17.58 Casing Landed at 2,029.83' 11 3/4", 47#, 8 R equipped with Baker guide shoe and float collar. .. " , OJ ~..' /.-..... . '- '- COMPLETION REPORT SWANSON RIVER UNIT WEn.. NO. 21-27 SECTION 27 (proj.) T. ;-3 N., R.. 9 w'.: òE~JAIill B & M ŠTArroARD OIL CO. OF CALIFORNIA, W.O.I. :-OPEBATOR Page 4. March 2lt 1961 QQut!tPolsg Cut conductor pipe. Had water flow between conductor and casing. Ran 1" pipe to 10' in annulus. Pumped in cement to surt'ace and stopped 'Water flow., Commenced flanging up. þiarch 22, 1961 Flanged up. Installed and tested BOPE with 1500 psi. OK. Tested Blind Rams with 1500 psi, 15 mine. OK. Tested Kelly Cock, pipe rams and H;ydril with 1500 psi, 15 mins. . OK. Drilled out cement and shoe. Drilled 10 5/8" hole 2,035 .. 2,885' . 850' drilled 80 pet' mud March 23, 1961 Drilled 10 5/8" hole 2,885 .. 4,112' 1,227' drilled Drilled 9 7/8" hole 4,112 .. 85' drilled 81 pet' mud 4,197' March 24 .. March 31, 1961 Drilled 9 7/8" hol~ 4,197 .. 81 - 95 pet' mud 7,489' 3,292' drilled !t~ril 1, 1961 ü>st circulation. Pulled to 3,000 " not regained. Pulled out. Cut mud back to 94 ~ct'. Lost 150 bbls. Drilled 9 7/8" hole 7,489 .. 7,609' 99 pet' mud 120' drilled April 2, 1961 Mud 95 pc:! at 8:00 AM. Lost circulation, 1 bbl. Lost every 5 mine. Increased mud weight from 95 pct' to 98 pet' to prevent gas entry. Full circulation ob- tained. Drilled 9 7/811 hole 1,609 .. 7,126' 98 pct' mud 111' drilled #4 ...... .~ (2--2..7 SIO3-SRU#~ ~ Questions I Concerns: 1. Unocal interprets the 62-5 sand in the offset SRU 21-27 well is NOT connected to the correlative sand in SRU~. Why? '~7 2. What is nature of permeability barriers? How can they be confirmed? How can they be better located? (Issue of Waste) 3. Cement across corresponding sands in nearby well SRU #21-27 is a concern. 7" production casing was run from surface to 11,142', and cemented with 2,200 sacks. Cement was found in the casing at 9358 and cleaned out to 11000'. CBL shows top of good cement at 9000', or about 2700' below the proposed injection interval. 4. Proposed injection pressures must be conclusively demonstrated to NOT cause fracturing of the thin (13 foot) claystone that separates the 62-5 sand from 51 feet of overlying, water-bearing sand. $'. 2./Z---%lr Ev¿~ f u,d/ ~ky;5 . c.. P,þ.r ~ ~ ~ <9.. ~ .d)'$~;:- NV2J '-, ~ -e[J U I va.f2w.J- cfl >rf /cO> . -fD <4~c Ie PY¿fVJ/f k 12--¿\,j'3o 7' 2-(2-2-/ - 2,/ - Z, 7 .- ~~~~~~~~~~~~~~~***~******%*******%*****************%%%*****%**********%%*********%********************** * P.01 * * ..r--- TRANSACTION REPORT'~ * * APR-29-04 MaN 04:19 PM * * * * SEND (M) * * * * DATE START RECEIVER TX TIME PAGES TYPE NOTE M~ DP * * * * APR-29 04:18. PM 2637698 38" 2 SEND ( M) OK 102 * * - * * * * TOTAL 38S PAGES: 2 * * ~ ******************************************************************************************************** ..,- . ""'-~_.. d' '-"".'-."'.,", ~- '.., .". - ,,--,~, ALASKA OIL & ~AS.CONSERVATION COMMISSION .. . 333 W. 7TH AVE, SUITE 100 ANCHORAGE, AK 99501-3539 . .. ...., .. PACSIMILE TR.ANSM.IT'tAL SHEET , . , -. :~~~~O'- ~~~ ,.- "\0:1. ,C~,¡1ltY\ß\~.'- DATE:!,/\ ' . ' , , ", ~/~\'()~ TOTAL NO. OF PAGES INCLuDING CoVER.: ~,-- .. .. FAX NUMBÈl\: PHÒNENUMBER:' '-" . ",:' ,"" ~ I) SENDER'S nnRENcÊ NmmEfu' M:' - - ' ~La.~'- fl.oC:\<3 ' , YOUR REFER.1£NCE NuMBER: " " j 93J ~ 1~_~ ... "" ," 0 UR.GENT 0 FOR REVIEW 0 PLEASE COMMENT D PLEASE gPLY 0 PLEA'>£ JŒCYc.'u NOTES/COMMÈNrs: ".. - "".>..--' ,"-- #3 ~ Unocal Alaska ~. Union Oil Company of Ca, ,a 909 West 9th Avenue, P.O. cox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL8 March 25, 2002 Ms. Camille Oechsli Taylor Mr. Dan Seamount Ms. Julie Heusser Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501-3539 Re: REVISION TO THE APPLICATION FOR INJECTION ORDER FOR GAS STORAGE FOR WELL KGSF #2, SWANSON RIVER FIELD, KENAI GAS STORAGE FACILITY Dear Commissioners: On March 6,2002 Unocal submitted an Application for Injection Order for Gas Storage for Well KGSF #2, Swanson River Field, Kenai Gas Storage Facility. In that application Unocal stated that Well KGSF #2 would be a redrill of Well SRU 212-27 into the depleted Tyonek 62-5 sand. After submitting the application Unocal tested the uphole Tyonek 59-2 sand and found it to be productive in Well SRU 212-27. Consequently Unocal requests having Well KGSF#2 be a redrill of idle SRU 12-27 into the Tyonek 62-5 sand instead of SRU 212-27. The two wells were drilled from the same drilling pad and are 167' from each other at surface. The impact of this change is small as both wells have similar casing designs, the target interval for injection has not changed, and the previously submitted application contains wellbore schematics and cement histories for both wells. Please contact Gary Orr at 263-7658 if you have any questions regarding this change. Sincerely, ìd~fi Ò~ Gary ðrr Advising Reservoir Engineer RECEIVED Cc: Greg Noble - Bureau of Land Management MAR 2 8 200¿ Alaska 011 & Gal COllI. CGnImiIsion ArdftJrIge #2 STATE OF ALASKA ADVERTISING ORDER F AOGCC R 333 W 7th Ave, Ste 100 0 Anchorage, AK 99501 M ¿ Anchorage Daily News POBox 149001 Anchorage, AK 99514 Type of Advertisement REF TYPE 1 VEN 2 ARD 3 NUMBER 02910 4 FIN AMOUNT Sy 01 2 3 4 REQUISITIONED BY: 02-902 (Rev. 3/94) ~ NOTICE TO PUBLISHER --\ ADVERTISING ORDER NO. INVOlc_.I.1UST BE IN TRIPLICATE SHOWING ADVERTISING ORDER N(,., vt:RTIFIED AFFIDAVIT OF PUBLICATION (PART2 OF THIS FORM) WITH ATTACHED COpy OF AO-O2214031 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE x D Display AGENCY CONTACT Jody Colombie PHONE DATE OF A.O. March 19,2002 PCN Legal (907) 793 -1 ?-21 DATES ADVERTISEMENT REQUIRED: March 22, 2002 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Account #STOF0330 Advertisement to be published was e-mailed D Classified DOther (Specify) SEE A TT ACHED PUBLIC HEARING AOGCC, 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 AMOUNT DATE cc PGM I I TOTAL OF I PAGE 1 OF ALL PAGES$ 2 PAGES COMMENTS LC NMR 02140100 ACCT FY DIST LlO 73540 IDIVISION APPROVAL: Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM ~. "-", Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Gas Storage, Well KGSF #2, Swanson River Field Union Oil Company of California Union Oil Company of California by letter March 6, 2002 has requested an order authorizing gas storage by injection in well KGSF #2, Swanson River Field, Kenai Gas Storage Facility. The requested order would allow Unocal to commence injection of gas during the summer of 2002. The Commission has tentatively set a public hearing on this application for April 30,2002 at 9:00 am at the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 5:00 pm on April 8, 2002. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. In addition, a person may submit written comments regarding this application to the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. Written comments must be received no later than 5:00 pm on April 22, 2002, except that if the Commission decides to hold a public hearing, written comments must be received no later than 5:00 pm on April 30, 2002. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1221 before April 15, 2002. ú 0 {klvÁ . ~rf/ Cammy Oechsli Taylor, Chair Oil and Gas Conservation Commission Published March 22, 2002 ADN AO #02214031 STATE OF ALASKA ADVERTISING ORDER --.. NOTICE TO PUBLISHER ~ ADVERTISING ORDER NO. INVOIC" MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., "ERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COpy OF AO-O2214031 ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC R 333 West ih Avenue, Suite 100 0 Anchorage, AK 99501 M AGENCY CONTACT DATE OF A.O. ~ Anchorage Daily News POBox 149001 Anchorage, AK 99514 Jody Colombie M~rch 19, ?002 PHONE PCN (907) 793 -1 ?? 1 DATES ADVERTISEMENT REQUIRED: March 22, 2002 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Account #STOF0330 United states of America AFFIDAVIT OF PUBLICATION REMINDER State of ss 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. 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 day of 2002, and thereafter for - consecutive days, the last publication appearing on the - day of . 2002, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This - day of 2002, Notary public for state of My commission expires 02-901 (Rev. 3/94) Page 2 AO.FRM PUBLISHER }- ~ Anchorage Daily News Affidavit of Publication 1001 Northway Drive, Anchorage, AK 99508 AD# PO PRICE PER DAY DATE ACCOUNT 350159 03/22/2002 STOF0330 $137.00 $137.00 02214031 STATE OF ALASKA THIRD JUDICIAL DISTRICT Lorene Solivan, being first duly sworn on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was' printed in an office maintained at the aforesaid place of, publication of said newspaper. That the annexed is <lcoPy of an advertisemenr as it was puolished in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of said period. That the fun amount of the fee charged for the foregoing lication is not in excess of the rate charged private individu s, Signed ) g~ Subscribed and sworn to me before this date: ..3 ..;22 -0 G-- Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska MY COMMISSION EXPIRES: /--- 7-P b ~' \\lrr(ff(rfrr ~cI£. ' ,\.\\~"~" ~~!O~rr~ )~ ~~~"""~R;;'~ ~ - - ~ ~~. O"{'" r'. -:::: ~ (): ~ ....- .- § : PUÐ\.\V .: is 3: "'" .....S liq... ~ .dI .. c3"""'...i ~~Q: ~1}: ar þ.~' ',~$ ~/-:% '... . .", :/.1.1 ~iQJ ~\ ,'\ ' IJJ})))))1)' . OTHER CHARGES OTHER CHARGES #2 GRAND TOTAL $0.00 $0.00 $137.00 $137.00 $0.00 $0.00 IÌIQticeQfP(bllc;'H.eariI19 STATE OF ALASKA . A.laska Oil and Gas Conservation.Commission ~re:l~asstorage, Well KGSF #2, .Swanson River Union 011 Company of California , Unian Oil çompany of COlifornia by;letter March 6, 2002 has requested a.n order authorizing gas stor- age by inlection inwellKGSF #2, Swansan Riyer Field, of<enai Gas StorageF!1èility,Therequested order Would OIl!1w lJnocalto commence injection at gas .dùring the summer of 2002. The Commission h!1s tentatively set a Public hear- ing!)n thjsapplication fofAPrii 30, 2002 at 9:00 om af the Alaska Oil and Gas Canservation Commis- sion at 333 West 7th Avenue, Suite 100, AnchorDge, AI.aska 99501. A Person may request that the tenta- tivelY scheduled hearing þè .held by filing a writ- ten request with the Commission no later than 5'00 pm on April 8, 2002. ' . . ' If a requestfora hearing is not timely fiied, the Commission Wi." consider'thè issuance of an order without a hl1afing. To learn if the Commission will hc¡ld the puþ."chearing, pl~asøcaIl793'1221. ,In addition, a Person may submit written com- ments reg(lrding this application .to the Alaska Oil and GasCanservation. Commission 'at 333 West 7th AvenuE!, Suite lOa; Anchor(1ge, Alaska 99501. Wrif- ten comments must be received no later than 5:00 pm on Apr." 22, 2002, except that 'if the Commis- sion decides to hold a pùblichearing, written comm~nts must be received no 'Iater than.5:00 pm on April 30, 2002. '. : If yoU 9re aÞe.r~on. y.!ith.O disability whomay-neecLJ a speqal, modlflcàt(jn- 10 order ta còmmerit or to ! attend. the public hearing, please contact Jody Co- 0 lombie at, 793-1221 before April 15,2002, Commy Oeçhsli TaYlor, Chair Oil qnd Ga.sConservation Commission Publishedj March 22, 2002 ...-- RECEIVED MAR 2 9 2002 AI8a 011 & GII CønI. CCInImi n Ion Aftdtof8gI Legal Notices '-"', ---, Subject: Legal Notices Date: Tue, 19 Mar 2002 15:31:25 -0900 From: Jody Colombie <jody - colombie@admin.state.ak.us> To: lsolivan@adn.com Lorene: I am e-mailing you three ad orders at the same time. Please send confirmation that you have received and processed these. Jody '------- ---,~_. , _.".,---, .".",..",~"""."" "',"u ,."",, .,..",.".,. "w"""'.",.,,. ... . ""'..., """""..,,,., '" ¡ ! Name: lAd Order form.doc i . ~ lAd Order form.doc: Type: WINWORD File (applicationlmsword)1 ¡Encoding: base64 I w.c",."""""",.""... . ",.",.,..,,""",. """""'...."" ",."",..",."..". "....",' r"'-"'W""""""" ""~','--""'~'" . "",-,." "w"""". -"--~"""~""""'--""-"'--""'I i Name: 2Ad Order form.doc I 112Ad Order form.doc! Type: WINWORD File (applicationlmsword)1 "--""""- ". -,_.l~~~o din,~: ~~~,~~~""-"'_.--"'--,-,~-, .___"",1 "", I Name:3AdOrderfo~.doc. . ¡ : 113Ad Order form.doc¡ Type: WINWORD Flle (apphcatlOnlmsword)i ~-'" : .~n~!>~ing: ~_~~~64", "'" ",- -_. "". w_. i . "', . ,.",., ._-~' ."".""-,,.,....,.,. .", .--""."". . ~ I Name: NoticeAnchorPointl.doc 11 NoticeAnchorPointl.doc I Type: WINWORD File (applicationlmsword): -""","'" tEncoding:,?a~~?4 . """"""""""",,"'" ,.,.""'~~".".."""'..,",...,... . -,-""""""""""""""?-"',"""" '""",' """"""""'--..'" """"'....."",,, ; Name: NoticeSwansonRiverStorage.doc I ! ~NoticeSwansonRiverStorage.doc! Type: WINWORD File (applicationlmsword)! :,..""""""",..."""',, .,~,~""""".",.,-",! .~n~~~~,~_:,~~~~~,-""",."""",."",-" ,I """"""""""""""""""""""-'~"""-""""""'-"""""""""'.,-""""""""..."""",..."""",.""..""... . ~-""""""""""""'-""'I ¡ Name: NoticeNicolaiCreek.doc ¡ ~NoticeNicolaiCreek.docl Type: WINWORD File (applicationlmsword) , I Encoding: base64 t ~"""""--"""""""""""""""""""'-"""""""""""~'~"""""""""""""""""'"_..".".....",.."".,..~""",--",."...""""""",~""""..."""""",-"""",..",.",""","'""."" 1 of 1 3/19/023:31 PM Re: Legal Notices "'"-.. -.. Subject: Re: Legal Notices Date: 20 Mar 200209:43:07 -0900 From: Lorene Solivan <lsolivan@adn.com> To: Jody Colombie <jody_colombie@admin.state.ak.us> Thank you Jody, all is good to go with these three ads. They will publish on the 22n Lorene 257-4296 On Tuesday, March 19, 2002, Jody Colombie <jody_colombie@admin.state.ak.us> wrote: >Lorene: > >I am e-mailing you three ad orders at the same time. Please send >confirmation that you have received and processed these. > >Jody > > 1 of! 3/20/02 10:38 AM NY PUBLIC LIBRARY DIV E, GRAND CENTRAL STATION POBOX 2221 NEW YORK, NY 10163-2221 US MIN MGMT SERV, CHIEF OCS STATS & INFO 381 ELDEN ST MS 4022 HERNDON, VA 20170-4817 TECHSYS CORP, BRANDY KERNS PO BOX 8485 GATHERSBURG, MD 20898 SD DEPT OF ENV & NATRL RESOURCES, OIL & GAS PROGRAM 2050 W MAIN STE #1 RAPID CITY, SD 57702 LINDA HALL LIBRARY, SERIALS DEPT 5109 CHERRY ST KANSAS CITY, MO 64110-2498 10GCC, POBOX 53127 OKLAHOMA CITY, OK 73152-3127 BAPIRAJU 335 PINYON LN COPPELL, TX 75019 STANDARD AMERICAN OIL CO, AL GRIFFITH POBOX 370 GRANBURY, TX 76048 H J GRUY, ROBERT RASOR 333 CLAY STREET SUITE 3850 HOUSTON, TX 77002 CHEVRON, PAUL WALKER 1301 MCKINNEY RM 1750 HOUSTON, TX 77010 r'- OFFICE OF THE GOVERNOR, JOHN KATZ STE 518 444 N CAPITOL NW WASHINGTON, DC 20001 LIBRARY OF CONGRESS, STATE DOCUMENT SECTION EXCH & GIFT DIV 10 FIRST ST SE WASHINGTON. DC 20540 US GEOLOGICAL SURVEY, LIBRARY NATIONAL CTR MS 950 RESTON, VA 22092 AMOCO CORP 2002A, LIBRARY/INFO CTR POBOX 87703 CHICAGO, IL 60680-0703 ALFRED JAMES III 107 N MARKET STE 1000 WICHITA, KS 67202-1811 R E MCMILLEN CONSULT GEOL 202 E 16TH ST OWASSO, OK 74055-4905 US DEPT OF ENERGY, ENERGY INFORMATION ADMINISTRATION MIR YOUSUFUDDIN 1999 BRYAN STREET STE 1110 DALLAS, TX 75201-6801 XTO ENERGY, MARY JONES 810 HOUSTON ST STE 2000 FORT WORTH, TX 76102-6298 PURVIN & GERTZ INC. LIBRARY 2150 TEXAS COMMERCE TWR 600 TRAVIS ST HOUSTON, TX 77002-2979 OIL & GAS JOURNAL, BOB WILLIAMS 1700 W LOOP SOUTH STE 1000 HOUSTON, TX 77027 ~ ARENT FOX KINTNER PLOTKIN KAHN, LIBRARY WASHINGTON SQ BLDG 1050 CONNECTICUT AV NW WASHINGTON, DC 20036-5339 U S DEPT OF ENERGY, PHYLLIS MARTIN MS EI823 1000 INDEPENDENCE SW WASHINGTON, DC 20585 DPC, DANIEL DONKEL 2121 NORTH BAYSHORE DR #616 MIAMI, FL 33137 ILLINOIS STATE GEOL SURV. LIBRARY 469 NATURAL RESOURCES BLDG 615 E PEABODY DR CHAMPAIGN, IL 61820 UNIV OF ARKANSAS. SERIALS DEPT UNIV LIBRARIES FAYETTEVILLE, AR 72701 OIL & GAS JOURNAL, LAURA BELL POBOX 1260 TULSA, OK 74101 DEGOL YER & MACNAUGHTON, MIDCONTINENT DIVISION ONE ENERGY SQ, STE 400 4925 GREENVILLE AVE DALLAS, TX 75206-4083 SHELL WESTERN E&P INC, G.S. NADY POBOX 576 HOUSTON, TX 77001-0574 RAY TYSON 2016 MAIN #1415 HOUSTON, TX 77002-8844 PETRAL CONSULTING CO, DANIEL L LIPPE 9800 RICHMOND STE 505 HOUSTON, TX 77042 AURORA GAS, G. SCOTT PFOFF 10333 RICHMOND AVENUE, STE 710 HOUSTON. TX 77042 MARATHON OIL CO, GEORGE ROTHSCHILD JR RM 2537 POBOX 4813 HOUSTON, TX 77210 EXXON EXPLOR CO, LAND/REGULATORY AFFAIRS RM 301 POBOX 4778 HOUSTON, TX 77210-4778 PETR INFO, DAVID PHILLIPS POBOX 1702 HOUSTON, TX 77251-1702 EXXONMOBIL PRODUCTION COMPANY, GARY M ROBERTS RM 3039 POBOX 2180 HOUSTON, TX 77252-2180 CHEVRON CHEM CO, LIBRARY & INFO CTR POBOX 2100 HOUSTON. TX 77252-9987 WATTY STRICKLAND 2803 SANCTUARY CV KATY, TX 77450-8510 INTL OIL SCOUTS, MASON MAP SERV INC POBOX 338 AUSTIN, TX 78767 ROBERT G GRAVELY 7681 S KIT CARSON DR LITTLETON, CO 80122 EVERGREEN WELL SERVICE CO., JOHN TANIGAWA 1401 17TH ST STE 1200 DENVER, CO 80202 ~ GAFFNEY, CLINE & ASSOC., INC., LIBRARY 1360 POST OAK BLVD., STE 2500 HOUSTON, TX 77056 UNOCAL, REVENUE ACCOUNTING POBOX 4531 HOUSTON, TX 77210-4531 TEXACO EXPLORATION & PRODUCTION INC, CORRY WOOLINGTON PO BOX 36366 HOUSTON, TX 77236 PHILLIPS PETROLEUM COMPANY, WALLEN HUCKABAY PO BOX 1967 HOUSTON, TX 77251-1967 EXXONMOBIL PRODUCTION COMPANY, J W KIKER ROOM 2086 POBOX 2180 HOUSTON, TX 77252-2180 MARATHON, Ms. Norma L. Calvert POBOX 3128, Ste 3915 HOUSTON, TX 77253-3128 TESORO PETR CORP, LOIS DOWNS 300 CONCORD PLAZA DRIVE SAN ANTONIO, TX 78216-6999 XTO ENERGY, DOUG SCHULTZE 3000 N GARFIELD SUITE 175 MIDLAND, TX 79705 DIANE SUCHOMEL 10507D W MAPLEWOOD DR LITTLETON, CO 80127 US GEOLOGICAL SURVEY, LIBRARY BOX 25046 MS 914 DENVER, CO 80225-0046 ~ MARK ALEXANDER 7502 ALCOMITA HOUSTON, TX 77083 / EXXON EXPLORATION CO., T E ALFORD POBOX 4778 HOUSTON, TX 77210-4778 CHEVRON USA INC., ALASKA DIVISION ATTN: CORRYWOOLINGTON POBOX 1635 HOUSTON, TX 77251 WORLD OIL, DONNA WILLIAMS POBOX 2608 HOUSTON, TX 77252 PENNZOIL E&P, WILL D MCCROCKLIN POBOX 2967 HOUSTON, TX 77252-2967 ACE PETROLEUM COMPANY, ANDREW C CLIFFORD PO BOX 79593 HOUSTON, TX 77279-9593 JIM WHITE 4614 BOHILL SAN ANTONIO, TX 78217 BABCOCK & BROWN ENERGY, INC., 350 INTERLOCKEN BLVD STE 290 BROOMFIELD, CO 80021 GEORGE G VAUGHT JR POBOX 13557 DENVER, CO 80201 C & R INDUSTRIES, INC." KURT SALTSGAVER 7500 W MISSISSIPPI AVE STE C4 LAKEWOOD, CO 80226-4541 JERRY HODGDEN GEOL 408 18TH ST GOLDEN, CO 80401 JOHN A LEVORSEN 200 N 3RD ST #1202 BOISE, ID 83702 MUNGER OIL INFOR SERV INC, POBOX 45738 LOS ANGELES, CA 90045-0738 ORO NEGRO, INC., 9321 MELVIN AVE NORTHRIDGE. CA 91324-2410 H L WANGENHEIM 5430 SAWMILL RD SP 11 PARADISE, CA 95969-5969 MARPLES BUSINESS NEWSLETTER, MICHAEL J PARKS 117 W MERCER ST STE 200 SEATTLE, WA 98119-3960 DUSTY RHODES 229 WHITNEY RD ANCHORAGE, AK 99501 DEPT OF ENVIRON CONSERVATION, DIV OF AIR & WATER QUALITY TOM CHAPPLE 555 CORDOVA STREET ANCHORAGE, AK 99501 AURORA GAS, J. EDWARD JONES 1029 W 3RD AVE. STE 220 ANCHORAGE. AK 99501 FOREST OIL, JIM ARLINGTON 310 K STREET STE 700 ANCHORAGE, AK 99501 ~ NRG ASSOC, RICHARD NEHRING POBOX 1655 COLORADO SPRINGS, CO 1655 80901- TAHOMA RESOURCES, GARY PLAYER 1671 WEST 546 S CEDER CITY, UT 84720 BABSON & SHEPPARD, JOHN F BERGQUIST POBOX 8279 VIKING STN LONG BEACH, CA 90808-0279 US GEOLOGICAL SURVEY, KEN BIRD 345 MIDDLEFIELD RD MS 999 MENLO PARK, CA 94025 ECONOMIC INSIGHT INC, SAM VAN VACTOR POBOX 683 PORTLAND, OR 97207 TRUSTEES FOR ALASKA, 1026 W. 4th Ave, Ste 201 ANCHORAGE, AK 99501 GUESS & RUDD, GEORGE LYLE 510 L ST, STE 700 ANCHORAGE, AK 99501 STATE PIPELINE OFFICE, LIBRARY KATE MUNSON 411 W 4TH AVE, STE 2 ANCHORAGE, AK 99501 DEPT OF ENVIRON CONSERVATION, DIV OF ENVIRONMENTAL HEALTH JANICE ADAIR 555 CORDOVA STREET ANCHORAGE, AK 99501 PRESTON GATES ELLIS LLP, LIBRARY 420 L ST STE 400 ANCHORAGE, AK 99501-1937 ..~ RUBICON PETROLEUM, LLC, BRUCE I CLARDY SIX PINE ROAD COLORADO SPRINGS, CO 80906 US GEOLOGICAL SURVEY, LIBRARY 2255 N GEMINI DR FLAGSTAFF, AZ 86001-1698 ANTONIO MADRID POBOX 94625 PASADENA, CA 91109 SHIELDS LIBRARY, GOVT DOCS DEPT UNIV OF CALIF DAVIS, CA 95616 US EPA REGION 10, THOR CUTLER OW-137 1200 SIXTH AVE SEATTLE,WA 98101 DEPT OF REVENUE, OIL & GAS AUDIT DENISE HAWES 550 W 7TH AV STE 570 ANCHORAGE, AK 99501 DEPT OF REVENUE, BEVERLY MARQUART 550 W 7TH AV STE 570 ANCHORAGE, AK 99501 DEPT OF REVENUE, CHUCK LOGSTON 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 DEPT OF REVENUE, DAN DICKINSON, DIRECTOR 550 W 7TH AVE. SUITE 500 ANCHORAGE. AK 99501 ALASKA DEPT OF LAW, ROBERT E MINTZ ASST ATTY GEN 1031 W 4TH AV STE 200 ANCHORAGE. AK 99501-1994 GAFO,GREENPEACE PAMELA MILLER 125 CHRISTENSEN DR. #2 ANCHORAGE, AK 99501-2101 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS BRUCE WEBB 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, 550 W 7TH AVE, SUITE 1200 ANCHORAGE, AK 99501-3560 ALASKA JOURNAL OF COMMERCE, ED BENNETT 2000 INTL AIRPORT W #A10 ANCHORAGE, AK 99502 N-I TUBULARS INC, 3301 C Street Ste 209 ANCHORAGE, AK 99503 YUKON PACIFIC CORP, 1400 W BENSON BLVD STE 525 ANCHORAGE, AK 99503 ANADRI LL -SCH LU MBE RGE R, 3940 ARCTIC BLVD #300 ANCHORAGE, AK 99503-5711 JAMES E EASON 8611 LEEPER CIRCLE ANCHORAGE, AK 99504-4209 AMERICA/CANADIAN STRATIGRPH CO, RON BROCKWAY 4800 KUPREANOF ANCHORAGE, AK 99507 THOMAS R MARSHALL JR 1569 BIRCHWOOD ST ANCHORAGE, AK 99508 /-',\ DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS TIM RYHERD 550 W 7th AVE STE 800 ANCHORAGE, AK 99501-3510 DEPT OF NATURAL RESOURCES, DIV OIL & GAS WILLIAM VAN DYKE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JULIE HOULE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 AK JOURNAL OF COMMERCE, OIL & INDUSTRY NEWS ROSE RAGSDALE 2000 INTL AIRPORT RD W #A10 ANCHORAGE, AK 99502 HDR ALASKA INC, MARK DALTON 2525 C ST STE 305 ANCHORAGE, AK 99503 ANADARKO, MARK HANLEY 3201 C STREET STE 603 ANCHORAGE. AK 99503 FINK ENVIRONMENTAL CONSULTING, INC.. THOMAS FINK, PHD 6359 COLGATE DR. ANCHORAGE, AK 99504-3305 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC DICK FOLAND 6881 ABBOTT LOOP RD ANCHORAGE, AK 99507 BUREAU OF LAND MANAGEMENT, GREG NOBLE 6881 ABBOTT LOOP ROAD ANCHORAGE, AK 99507 UOA/ ANCHORAGE. INST OF SOCIAL & ECON RESEARCH TERESA HULL 3211 PROVIDENCE DR ANCHORAGE, AK 99508 /"""" DEPT OF REVENUE, OIL & GAS AUDIT FRANK PARR 550 W 7TH AVE STE 570 ANCHORAGE, AK 99501-3540 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JIM STOUFFER 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DNR, DIV OF OIL & GAS JAMES B HAYNES NATURAL RESRCE MGR 550 W 7TH AVE, SUITE 800 ANCHORAGE. AK 99501-3560 BRISTOL ENVIR AND ENG SERVICE. MIKE TORPY 2000 W. INT'L AIRPORT RD #C-1 ANCHORAGE, AK 99502-1116 BAKER OIL TOOLS, ALASKA AREA MGR 4710 BUS PK BLVD STE 36 ANCHORAGE, AK 99503 ALASKA OIL & GAS ASSOC. JUDY BRADY 121 W FIREWEED LN STE 207 ANCHORAGE. AK 99503-2035 ARLEN EHM GEOL CONSL TNT 2420 FOXHALL DR ANCHORAGE, AK 99504-3342 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC PETER J DITTON 6881 ABBOTT LOOP ROAD ANCHORAGE. AK 99507 US BLM AK DIST OFC, GEOLOGIST ARTHUR BANET 949 EAST 36TH AVE STE 308 ANCHORAGE, AK 99508 VECO ALASKA INC., CHUCK O'DONNELL 949 EAST 36TH AVENUE ANCHORAGE. AK 99508 TRADING BAY ENERGY CORP, PAUL CRAIG 5432 NORTHERN LIGHTS BLVD ANCHORAGE, AK 99508 US MIN MGMT SERV, RICHARD PRENTKI 949 E 36TH AV ANCHORAGE, AK 99508-4302 US MIN MGMT SERV, LIBRARY 949 E 36TH AV RM 603 ANCHORAGE, AK 99508-4363 JOHN MILLER 3445 FORDHAM DR ANCHORAGE, AK 99508-4555 PHILLIPS ALASKA, LAND MANAGER JIM RUUD P.O. BOX 100360 ANCHORAGE, AK 99510 PHILLIPS ALASKA, LAND DEPT JAMES WINEGARNER POBOX 10036 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, JOANN GRUBER ATO 712 POBOX 100360 ANCHORAGE. AK 99510-0360 AL YESKA PIPELINE SERV CO. PERRY A MARKLEY 1835 S BRAGAW - MS 575 ANCHORAGE, AK 99512 DAVID W. JOHNSTON 320 MARINER DR. ANCHORAGE, AK 99515 GERALD GANOPOLE CONSULT GEOL 2536 ARLINGTON ANCHORAGE, AK 99517-1303 ~ US MIN MGMT SERV, RESOURCE STUDIES AK OCS REGN KIRK W SHERWOOD 949 E 36TH AV RM 603 ANCHORAGE, AK 99508-4302 GORDONJ.SEVERSON 3201 WESTMAR CIR ANCHORAGE, AK 99508-4336 US MIN MGMT SERV, FRANK MILLER 949 E 36TH AV STE 603 ANCHORAGE, AK 99508-4363 USGS - ALASKA SECTION, LIBRARY 4200 UNIVERSITY DR ANCHORAGE, AK 99508-4667 ANCHORAGE TIMES, BERT TARRANT POBOX 100040 ANCHORAGE, AK 99510-0040 PHILLIPS ALASKA, STEVE BENZLER ATO 1404 POBOX 100360 ANCHORAGE, AK 99510-0360 PETROLEUM INFO CORP, KRISTEN NELSON POBOX 102278 ANCHORAGE, AK 99510-2278 AL YESKA PIPELINE SERV CO, LEGAL DEPT 1835 S BRAGAW ANCHORAGE, AK 99512-0099 JWL ENGINEERING, JEFF LIPSCOMB 9921 MAIN TREE DR. ANCHORAGE, AK 99516-6510 DAVID CUSATO 600 W 76TH AV#508 ANCHORAGE, AK 99518 ,-.., US MIN MGMT SERV, AK OCS REGIONAL DIR 949 E 36TH AV RM 110 ANCHORAGE, AK 99508-4302 US MIN MGMT SERV, RESOURCE EVAL JIM SCHERR 949 E 36TH AV RM 603 ANCHORAGE, AK 99508-4363 REGIONAL SUPRVISOR, FIELD OPERATNS, MMS ALASKA OCS REGION 949 E 36TH AV STE 308 ANCHORAGE, AK 99508-4363 CIRI, LAND DEPT POBOX 93330 ANCHORAGE, AK 99509-3330 PHILLIPS ALASKA, MARK MAJOR ATO 1968 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, LEGAL DEPT MARK P WORCESTER POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, KUP CENTRAL WELLS ST TSTNG WELL ENG TECH NSK 69 POBOX 196105 ANCHORAGE, AK 99510-6105 ANCHORAGE DAILY NEWS. EDITORIAL PG EDTR MICHAEL CAREY POBOX 149001 ANCHORAGE, AK 99514 NORTHERN CONSULTING GROUP, ROBERT BRITCH, P.E. 2454 TELEQUANA DR. ANCHORAGE, AK 99517 ARMAND SPIELMAN 651 HILANDER CIRCLE ANCHORAGE, AK 99518 ASRC, CONRAD BAGNE 301 ARCTIC SLOPE AV STE 300 ANCHORAGE, AK 99518 OPSTAD & ASSOC, ERIK A OPSTAD PROF GEOL POBOX 190754 ANCHORAGE, AK 99519 MARATHON OIL CO, OPERATIONS SUPT W.C. BARRON POBOX 196168 ANCHORAGE. AK 99519-6168 UNOCAL, KEVIN TABLER POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA) INC, PETE ZSELECZKY LAND MGR POBOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, SUE MILLER POBOX 196612 MIS LR2-3 ANCHORAGE, AK 99519-6612 L G POST O&G LAND MGMT CONSULT 10510 Constitution Circle EAGLE RIVER, AK 99577 DEPT OF NATURAL RESOURCES, DGGS JOHN REEDER POBOX 772805 EAGLE RIVER, AK 99577-2805 PHILLIPS PETROLEUM CO. ALASKA OPERATIONS MANAGER J W KONST P 0 DRAWER 66 KENAI, AK 99611 NANCY LORD PO BOX 558 HOMER, AK 99623 ~. HALLIBURTON ENERGY SERV, MARK WEDMAN 6900 ARCTIC BLVD ANCHORAGE, AK 99518-2146 JACK 0 HAKKILA POBOX 190083 ANCHORAGE, AK 99519-0083 MARATHON OIL CO, LAND BROCK RIDDLE POBOX 196168 ANCHORAGE, AK 99519-6168 EXXONMOBIL PRODUCTION COMPANY, MARK P EVANS PO BOX 196601 ANCHORAGE, AK 99519-6601 BP EXPLORATION (ALASKA) INC, INFO RESOURCE CTR MB 3-2 POBOX 196612 ANCHORAGE, AK 99519-6612 AMSINALLEE CO INC, WILLIAM 0 VALLEE PRES PO BOX 243086 ANCHORAGE, AK 99524-3086 PINNACLE, STEVE TYLER 20231 REVERE CIRCLE EAGLE RIVER, AK 99577 COOK INLET KEEPER, BOB SHAVELSON PO BOX 3269 HOMER, AK 99603 DOCUMENT SERVICE CO, JOHN PARKER POBOX 1468 KENAI, AK 99611-1468 PENNY VADLA POBOX 467 NINILCHIK, AK 99639 ~ TESORO ALASKA COMPANY, PO BOX 196272 ANCHORAGE, AK 99519 ENSTAR NATURAL GAS CO, PRESIDENT TONY IZZO POBOX 190288 ANCHORAGE, AK 99519-0288 UNOCAL, POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA), INC., MARK BERLINGER MB 8-1 PO BOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, MR. DAVIS, ESO POBOX 196612 MB 13-5 ANCHORAGE, AK 99519-6612 D A PLATT & ASSOC, 9852 LITTLE DIOMEDE CIR EAGLE RIVER, AK 99577 JAMES RODERICK PO BOX 770471 EAGLE RIVER, AK 99577-0471 RON DOLCHOK PO BOX 83 KENAI, AK 99611 KENAI PENINSULA BOROUGH, ECONOMIC DEVEL DISTR STAN STEADMAN POBOX 3029 KENAI, AK 99611-3029 BELOWICH, MICHAEL A BELOWICH 1125 SNOW HILL AVE WASILLA, AK 99654-5751 PACE, SHEILA DICKSON POBOX 2018 SOLDOTNA, AK 99669 VALDEZ PIONEER, POBOX 367 VALDEZ, AK 99686 UNIV OF ALASKA FAIRBANKS, PETR DEVEL LAB DR V A KAMATH 427 DUCKERING FAIRBANKS, AK 99701 RICK WAGNER POBOX 60868 FAIRBANKS, AK 99706 DEPT OF NATURAL RESOURCES, DIV OF LAND REG MGR NORTHERN REGION 3700 AIRPORT WAY FAIRBANKS, AK 99709-4699 RICHARD FINEBERG PO BOX416 ESTER, AK 99725 SENATOR LOREN LEMAN STATE CAPITOL RM 113 JUNEAU, AK 99801-1182 ".-., JAMES GIBBS POBOX 1597 SOLDOTNA, AK 99669 AL YESKA PIPELINE SERVICE CO, VALDEZ CORP AFFAIRS SANDY MCCLINTOCK POBOX 300 MS/701 VALDEZ. AK 99686 NICK STEPOVICH 543 2ND AVE FAIRBANKS. AK 99701 FAIRBANKS DAILY NEWS-MINER, KATE RIPLEY POBOX 70710 FAIRBANKS, AK 99707 K&K RECYCL INC, POBOX 58055 FAIRBANKS, AK 99711 UNIV OF ALASKA FBX, PETR DEVEL LAB SHIRISH PATIL 437 DICKERING FAIRBANKS, AK 99775 DEPT OF ENVIRON CONSERV SPAR, CHRIS PACE 410 WILLOUGHBY AV STE 105 JUNEAU, AK 99801-1795 /""._,\ KENAI NATL WILDLIFE REFUGE, REFUGE MGR POBOX 2139 SOLDOTNA, AK 99669-2139 VALDEZ VANGUARD, EDITOR PO BOX 98 VALDEZ, AK 99686-0098 COOK AND HAUGEBERG, JAMES DIERINGER, JR. 119 NORTH CUSHMAN. STE 300 FAIRBANKS. AK 99701 C BURGLIN POBOX 131 FAIRBANKS, AK 99707 ASRC, BILL THOMAS POBOX 129 BARROW, AK 99723 UNIVERSITY OF ALASKA FBKS, PETR DEVEL LAB DR AKANNI LAWAL POBOX 755880 FAIRBANKS, AK 99775-5880 #1 ,,-... Unocal Alaska 1--- Union Oil Company of Calif 909 West 9th Avenue, P.O. Ie 4. 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL8 March 6, 2002 Ms. Camille Oechsli Taylor Mr. Dan Seamount Ms. Julie Heusser Alaska Oil and Gas Conservation Commission 333 W. yth Avenue, Suite 100 Anchorage, AK 99501-3539 Re: APPLICATION FOR INJECTION ORDER FOR GAS STORAGE FOR WEll KGSF #2, SWANSON RIVER FIELD, KENAI GAS STORAGE FACILITY Dear Commissioners: Attached for your review are two copies of Application for Injection Order for Well KGSF #2, which is a planned expansion of the Kenai Gas Storage Facility located within the Swanson River Field. The application is submitted by Union Oil Company of California (dba Unocal), as Operator. Upon your approval of this application and pending approval of a gas storage agreement with the Bureau of land Management, Unocal plans to commence injection of gas into this well for storage this summer. Please contact Gary Orr at 263-7658 if you have any questions regarding this application. Sincerely, 4~ Gary~r Advising Reservoir Engineer cc: Greg Noble -Bureau of land Management R. '.."=...'~.' 'lÝ.""'~ß=~"VFkt:¡"""D . ~e ,f=~' . . [i,= Y'J--m M¡~R 0 ? 2002 Alaska Oil & G;::§ Cons. Commission Anchorage ~ I~ SWANSON RIVER FIELD APPLICATION FOR INJECTION ORDER FOR GAS STORAGE WELL KENAI GAS STORAGE FACILITY #2 (KGSF #2) March 6, 2002 r"'. ~ APPLICATION FOR INJECTION ORDER FOR GAS STORAGE WELL KGSF #2 TABLE OF CONTENTS Section/Regulatory Citation Subject Page A. 20 AAC 25.402(c)(1) Plat 1 20 AAC 25.252(c)(1) B. 20 AAC 25.402(c)(2) Operators/Suñace Owners 1 20 AAC 25.252(c)(2) C. 20 AAC 25.402(c)(3) Affidavit 2 20 AAC 25.252(c)(3) D. 20 AAC 25.402(c)(4) Description of Operation 3 E. 20 AAC 25.402(c)(5) Pool Information 3 F. 20 AAC 25.402(c)(6) Geologic Information 3 20 AAC 25.252(c)(4) G. 20 AAC 25.402(c)(7) Well Logs 5 20 AAC 25.252(c)(5) H. 20 AAC 25.402(c)(8) Mechanical Integrity 5 20 AAC 25.252(c)(6) I. 20 AAC 25.402(c)(8) Casing Information 5 20 AAC 25.252(c)(6) J. 20 AAC 25.402(c)(9) Injection Fluid 6 20 AAC 25.252(c)(7) K. 20 AAC 25.402(c)(10) Injection Pressure 6 20 AAC 25.252(c)(8) L. 20 AAC 25.402(c)(11) Fracture Information 6 20 AAC 25.252(c)(9) M. 20 AAC 25.402(c)(12) Formation Fluid 7 20 AAC 25.252(c)(10) N. 20 AAC 25.402(c)(13) Aquifer Exemption 7 20 AAC 25.252(c)(11) O. 20 AAC 25.402(c)(15) Wells Within Area 7 20 AAC 25.252(c)(12) Number 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 ,'-'. /""- SWANSON RIVER FIELD APPLICATION FOR INJECTION ORDER FOR GAS STORAGE WEll KGSF #2 LIST OF ATTACHMENTS Description Cook Inlet location Map KGSF #2 location Map Structure Map of Tyonek 62-5 Sand SRU 212-27 log Section SRU 212-27 Production Data Volumetric Gas Reserve Estimate Material Balance P/Z Plot KGSF #2 Wellbore Schematic (As planned) Sample Gas Analysis leak Off Test for SCU 2438-4 leak Off Test for SRU 223-28 SRU 12-27 Well bore Schematic Cement Job Reports for SRU 12-27 SRU 314-27 Well bore Schematic Abandonment Reports for SRU 314-27 Cement Job Report for 7-5/8" Casing in SRU 314-27 SRU 21-27 Wellbore Schematic ./'""- . /"'... SWANSON RIVER FIELD KENAI GAS STORAGE FACILITY APPLICATION FOR INJECTION ORDER WELL KENAI GAS STORAGE FACILITY #2 (KGSF #2) March 6, 2002 Introduction In 2001, Unocal commenced operation of a gas storage pilot project within the boundaries of the Swanson River oil field. Unocal refers to this gas storage operation as the Kenai Gas Storage Facility. In order to expand the capacity of the Kenai Gas Storage Facility, Union Oil Company of California (dba Unocal), as operator of the Swanson River Field (SRF), requests an injection order for injection of gas for gas storage purposes into a well to be called KGSF #2. Well KGSF #2 is planned as a redrill of SRU 212-27 with a 500' lateral in the Tyonek 62-5 sand. Section A - Plat Attachment 1 is a regional map showing the location of the Swanson River Field relative to other fields in the Cook Inlet area. Attachment 2 is a plat showing the location of the proposed injection well and the surrounding wells in sections 22, 27, and 28. Section B - Operators/Suñace Owners The surface owners and operators within the area of this injection order and extending one-quarter mile beyond the boundary are: . Unocal . U.S. Department of the Interior, U.S. Fish & Wildlife Service 1 -- / . ~ . Section C - Affidavit Affidavit of Gary A. err STATE OF ALASKA THIRD JUDICIAL DISTRICT I, Gary A. err, declare and affirm as follows: 1. I am over 19 years of age. I am employed by Unocal as an Advisin'g Reservoir Engineer. I have personal knowledge of the matters set forth in this affidavit. On fY)V¡h~ t ,2002, the surface owners/operators listed in section B were provided a copy of this permit application. 2. DATED at Anchorage, Alaska this ----LV¡ tfÎ"~ ' 2002. h day of /J ;f~ 1/ ()~~ Gary A. err Subscribed and affirmed before me at Anchorage, Alaska on /V\A-ILt.1f t:-, ,2002. ~\\\\UIIIllIJIIIQb ~ """.M.~ ~ Cö"""""""~.i!; ~ ~ ...~~..?! ~ ~ '"$0 '. ~ ~ {NOTARY\ ~ :a : PUB : ii ~. \. LIC .: 10( ;:;:: ~ cPO .' T.§§ ~ ~"..?CI.23 21)\)~..'.L~ ~ ~ .,?;....~..... ...C:J~A ~ OF þ..\."~. '1/1111", ml\\\\\\~ ~A1~~ Notary Public in and for the State of Alaska 2..; . D My commission expires: (0' ~ 1- 2 ,r-- ~, Section D - Description of Operation Unocal proposes injecting gas into the depleted Tyonek 62-5 sand for gas storage purposes. The KGSF #2 well, a red rill of SRU 212-27, will be used for both injection and production. Well SRU 212-27 is the only well to have produced from this reservoir. SRU 212-27 will be redrilled with 500' of lateral into the 62-5 sand. The addition of the lateral is necessary to get the desired gas storage deliverability. The gas will be injected during the summer months and produced back in the winter months for sales. Section E - Pool Information The 62-5 sand of the Tyonek Formation is the proposed zone of injection. This depleted shallow gas reservoir is part of the Tyonek PA (8910086520-C). Gas from these reservoirs has typically been used on the lease for fuel. The Tyonek Participating Area (8910086520-C) is comprised of the stratigraphic interval the top of which correlates to the measured depths defined in the following wells: Well SRU 212-10 SRU 211-15 SRU 234-15 SRU 212-27 SCU 341-4 SCU 34-4 SCU 21-16 Top Tyonek P.A. Measured Depth 5764 5640 5639 5322 5304 5123 5512 The base of the Tyonek Participating Area is equivalent to the top of the Hemlock Participating Area as defined in Unocal's October 2, 1995 letter to the AOGCC requesting expansion of the Hemlock Pool. The Hemlock Pool is defined in that letter in the following Soldotna Creek Unit wells: 41-4 (10,085' -10880' MD), 43-4 (10,168'-10,920' MD), and 41A-8 (10,116'-10,880'). Section F - Geoloqic Information The Swanson River Field structure is a broad north-south trending anticline cut by a number of east-west trending normal faults. Oil and/or gas is produced from four formations at Swanson River Field. The shallowest gas production is from the Sterling Formation. The Sterling Formation extends to a depth of approximately 3500 feet and is comprised of thick sandstones, mudstones and coals deposited in a high-energy meandering to braided stream environment. 3 r---.. .~ Gas is also produced from the thinly bedded sands of the Beluga Formation that underlies the Sterling. These discontinuous sands were deposited in a lower energy stream system, and they are interlayered with abundant mudstones and coals. The Beluga Formation is approximately 2000 feet thick at Swanson River Field. The Tyonek Formation is comprised of meander belt and braided stream sandstones interlayered with mudstones and thick coals. The Tyonek Formation is approximately 5000 feet thick at Swanson River Field, and gas is produced from several sands in the upper and middle part of the formation, while oil production comes from the lowermost 100 feet the Tyonek (the Tyonek G Zone). Underlying the Tyonek is the main oil producing interval at Swanson River Field, the Hemlock Formation. The Hemlock Formation is 600 feet thick at Swanson River Field and is comprised of thick conglomeratic sandstones interlayered with thin mudstones and minor coal. The 62-5 sand is a Tyonek sand that is present across most of Swanson River Field; however, it is only gas bearing in sections 27 and 28. The 62-5 sand gas column is penetrated by wells SRU 212-27, SRU 12-27, SRU 43-28, SRU 41-33 and SRU 34-28 as seen in the 62-5 sand structure map (Attachment 3). . The attached log section for SRU 212-27 (Attachment 4) shows the 62-5 sand at depths from 6233 to 6253 feet measured depth (MD). Mudlog data indicates that the sand is fine to medium grained. The 62-5 sand is overlain by 13 feet of impermeable, claystone that is, in turn, overlain by 10 feet of coal, and 51 feet of water bearing sandstone. Underlying the 62-5 sand is 19 feet of impermeable siltstone and claystone that is, in turn, underlain by 21 feet of waterbearing sandstone. This waterbearing sandstone is underlain by over 230 feet of impermeable siltstone, claystone and coal. Porosity in the 62-5 sand, as calculated from the sonic log, ranges from 24% to 30%. These calculated porosities are affected by the presence of gas and are, in fact, somewhat lower. Applying the basic Archie equation with the following inputs: 1) sonic porosity, 2) m = 1.6,3) n = 1.8, and 4) Rw = 0.35 ohmm (10,000 ppm NaCI equiv.), results in Sw values averaging 47%. If the porosity is, in fact, 10% too high, then the true Sw would be 52%. The 62-5 perforations were added to SRU 212-27 well in September of 1997. The well was perforated from 6237 to 6254'. The peak gas rate occurred on 11- 28-97 at 4 MMCFPD. The well has produced a cumulative volume of 1.973 bcf from the 62-5 sand through January of 2001 (Attachment 5). Although the 65-7 was open from November 1996 to January 2001 its contribution is estimated to minimal as it was producing at low rates prior to the addition of the perforations in the 62-5 sand. 4 ~ ~ Initial volumetric estimates for the accumulation before the recompletion of SRU 212-27 were 3.04bcf (Attachment 6). The lower cumulative produced volumes indicate that this original volumetric estimate is inaccurately high. This inaccuracy is probably due to lower effective porosity values, and higher water saturations than originally expected. Material balance analysis of historical production and pressure data indicates an original gas in place of 2.9 bcf (Attachment 7). Using this figure for the original gas in place, the current recovery of 1.973 bcf corresponds to a 68% recovery. SRU 212-27 had produced all of its proven reserves from the 62-5 sand as of February 2001. The interval, which would not longer flow gas, was abandoned in February 2001 and the well recompleted into the 61-3 sand. The 61-3 sand has proven to be an uneconomical completion. Given the production history of the depleted Tyonek 62-5 sand, it should be a good gas storage reservoir. Section G - Well LoQs All open hole logs from wells in the Swanson River Unit are sent to the Commission as the logs are completed. Attachment 3 shows a log section for the proposed injection interval in well SRU 212-27. Section H - Mechanicallnteqritv The KGSF #2 well will be tested for mechanical integrity using the standard 30 minute annulus test as per 20 AAC 25.412. To confirm continued mechanical integrity, Unocal will monitor daily the injection rates and pressures and notify the AOGCC the next working day if the rates and pressures indicate pressure communication or leakage in any casing, tubing, or packer. The rate and pressure data will also be reported to the Commission on a monthly basis. Section I - CasinQ Information Attachment 8 is a wellbore schematic for the KGSF #2 well (proposed). The casing in SRU 212-27 was cemented in accordance with 20 ACe 25.252(b) and tested in accordance with 20 AAC 25.030(g) when completed. As evidenced in the attachment, the SRU 212-27 well is completed with 5.5" casing run and cemented down to a depth of 7800' MD and TVD. A DV collar was run in the casing string and is located at 4,430'. The bond log run 10/2/61 indicates a first stage cement top at 5800' and a second stage cement top at 2290'. The log indicates good cement bond in the proposed gas storage interval. ""-0"" 5 ~ ~ Production data from this zone is supportive of a good cement bond. Section J - Injection Fluid The type of fluid for proposed injection is gas. The fluid composition for the proposed injection is dry natural gas with a specific gravity of 0.59. The properties of the gas are shown in the gas sample taken included as Attachment 9. Initially the source of the injection fluid is from the Hemlock formation within the Swanson River Field. Gas was injected into the Hemlock formation over the period of 1962 to 1992 for pressure maintenance purposes. This gas, termed "rental gas", is methane imported primarily from the Kenai gas field and the Trading Bay Unit. The produced gas today contains some heavier hydrocarbon components that are removed through various liquid extraction processes. The outlet gas from these processes would be used for injection into KGSF #2. In the future gas from other fields in the Cook Inlet will be injected and stored in Kenai Gas Storage Facility wells during the summer months and redelivered during the winter months. The estimated maximum amount of gas to be injected daily is 14 mmcfd. The injection gas should be fully compatible with the Tyonek 62-5 formation, since this zone previously contained dry methane gas and was produced without any signs of formation damage. Section K - Injection Pressure Existing compression will be used for gas injection and production operations. The estimated average injection pressure is 2700 psi. The maximum injection pressure will be 3000 psi. The compressor plant maximum output pressure limits the maximum injection pressure. Section L - Fracture Information The proposed maximum injection pressures for the gas storage operation will not initiate fractures in the confining strata which might enable the injection or formation fluid to enter freshwater strata. 6 r--, ,,-...., The proposed maximum injection pressure for KGSF #2 in the 62-5 sand is 3000 psi tubing pressure (which is a .54 psi/ft gradient at the sand face). The injection pressure is limited by the compression capabilities at the Swanson River Field. leak off tests in wells SCU 2438-4 and SRU 223-28, both new drills in the last five years, show the fracture gradient at approximately 2000' to range from .8 to 1.1 psi/ft (see attachment 10 and 11). Original reservoir pressure in the 62-5 sand in SRU 212-27 is estimated at 2716 psi based on initial shut-in tubing pressure measurements of 2400 psi. Using the reservoir true vertical depth of 6245', this equates to an original pressure gradient of 0.435 psi/ft. Section M - Formation Fluid No samples exist of produced water from the proposed injection interval. Section N - AQuifer Exemption The proposed gas injection will be at a depth of approximately 6233-6252' TVD. As per 40 CFR 147.1 02(b) the aquifers in the Swanson River Field are exempted in accordance with 40 CFR 144.7(b) and 40 CFR 146.4. Section 0 - Wells Within Area Well SRU 12-27 is within a quarter mile of the proposed KGSF #2. A wellbore schematic is shown in attachment 12. The 13-3/8" shoe tested with 1550 psi surface pressure (with 73.5 pet mud in the hole puts the pressure test at 3051 psi at 2943' or 1.037 psi/ft) without breaking down. The 9-5/8" was set from 2736' to 7228'. The cement job of 500 sks of 116 pcf puts a theoretical top of cement at 5633', assuming 120% of calculated hole volume. The caliper log run two days prior to the cement job shows the hole to be close to gauge from 5820 to 7228'. The 9-5/8" X 13-3/8" liner lap did not initially test. The lap was squeezed and retested at 2000 psi surface pressure (with 91 pcf mud in the hole puts the pressure test at 3729 psi). The 9-5/8" liner was then perforated at 7208" and squeezed. The formation broke down under 2900 psi of surface pressure (with 91 pcf mud in the hole puts the breakdown pressure at 7454 psi or a fracture gradient of 1.03 psi/ft). The 5-1/2" production casing was run from 11492' to surface. The production casing was cemented in 2 stages. The second stage through a DV collar at 8178". A temperature log indicates a top of the second stage cement at 5410'. The portions of the drilling reports when the cement jobs occurred are attached as attachment 13. Well SRU 314-27 is within a quarter mile of the proposed KGSF #2. A wellbore schematic is shown in attachment 14. SRU 314-27 was abandoned in June 7 /---- .--. 1992 (reports are attached as attachment 15). Cement plugs were installed at 404',2,296', and 10,530'. The 7-5/8" casing string, which is located across the 62-5 sand (located at 6351' measured in this well), runs from surface to 10619' in 10-5/8" hole. The string was cemented in two stages. The first stage was 500 sacks of cement, pumped around the shoe. The second stage consisting of 1200 sacks was pumped through a DV collar at 8118'. Theoretical top of cement assuming 120% of calculated hole volume should be at 4302'. There are no caliper logs for this section of the well. A temperature rag run right after the cement job was not able to get below 4920'. The log did not find a cement top. The drilling report for the cement job on the 7-5/8" casing is shown in attachment 16. Well SRU 21-27 is within a quarter mile of the proposed KGSF #2. Unocal's geologic interpretation is that the 62-5 sand in SRU 21-27 is not connected to the 62-5 sand that was depleted by SRU 12-27. A wellbore schematic of SRU 21-27 is shown in attachment 17. The1t-;;3/4" surface casing in SRU 21-27 was run from surface to 2029'. It was cemented with 1350 sacks of cement. Full circulation throughout the job and good returns. The 7" production casing was run from surface to 11,142'. It was cemented with 2,200 sacks with an average slurry weight of 116 pcf. The plug was not bumped. Cement was found in the casing at 9358' and cleaned out to 11000'. A cement bond log shows the top of good cement at 9000'. - 8 I , , , , , I __L___- i : i I I I I II L/" I ; ì ' iU--N--n---O--'C-----A-- r-,[---.~ ~ -------t---------r-------L~l!~~~~ --t------- _¡I- -------i---------t--------t------- t--. 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I I I I I I I --- ---- ~ ~C?> <o() / .-28* SI /"'-.. ~ SWANSO~ RIVER' UNIT: + 23-22 SI ~ ~, <o() / 14-22 :+- SI ! Mile Radi us ~ ,'l--' + - /' - =-- --- :::::- - ~1-27~I--<O - ~ / ,~ t... 'l-- / "- \J~~ <0 'I' / > C(j 41-28 +/ 1/ 2t-27-+- \ / \ Prorused KGSF #2 \ Combletion ~ ~~ I r ~ <o() ~ I I 12-27. ~~~ + I I 212-27 "* ~ I \J~ / 32-27 C(j / /27 / / / /' - --- ~ ~<þ <0' / , 1\\ ~ 1 \, :-\" "- <o() , ' / .......... 43-28 * SI I I -- I I I I I 23-27 SI , 314-27RD 31r-27RD-2 G 314-27 I 1-- ~ 1/, ,', t I I I I I ATTACHMENT 2 - L: \Ðm#i n g\Gfef tin ~ A N$OtII/ 6 2 -=5=S t r llCÌ=Åt ~ ..eiw.9---- :.II + /""', /~ Attachment 5 SRU 212-27 Production Report for the 62-5 Sand Completion Daily Gas Cumulative Daily Water Rate Gas Volume Rate Cumulative Water Date (MCFPD) (MMCF) (BWPD) Volume (MBBlS) Sep-97 571 17 0 0 Oct-97 2086 82 0 0 Nov-97 2819 166 0 0 Dec-97 3400 272 0 0 Jan-98 3104 368 0 0 Feb-98 2977 451 0 0 Mar-98 3190 550 0 0 Apr-98 3108 643 0 0 May-98 2836 731 0 0 Jun-98 2609 810 0 0 Jul-98 2817 897 0 0 Aug-98 2805 984 0 0 Sep-98 1775 1037 0.3 0.01 Oct-98 1490 1083 0 0.01 Nov-98 1504 1128 0 0.01 Dec-98 1787 1184 0 0.01 Jan-99 1552 1232 0 0.01 Feb-99 1724 1280 0 0.01 Mar-99 1192 1317 0 0.01 Apr-99 1421 1360 0 0.01 May-99 1475 1405 0 0.01 Jun-99 1130 1439 0 0.01 Jul-99 797 1464 0 0.01 Aug-99 1416 1508 0 0.01 Sep-99 1373 1549 0 0.01 Oct-99 997 1580 0 0.01 Nov-99 1346 1620 0 0.01 Dec-99 1207 1658 0 0.01 Jan-OO 1099 1692 0 0.01 Feb-OO 1092 1724 0 0.01 Mar-OO 964 1753 0 0.01 Apr-OO 773 1777 1.33 0.05 May-OO 1000 1808 0.74 0.07 Jun-OO 939 1836 0 0.07 Jul-OO 669 1857 0 0.07 Aug-OO 1074 1890 4.45 0.21 Sep-OO 992 1920 6.17 0.39 Oct-OO 790 1944 6.32 0.59 Nov-OO 554 1961 0 0.59 Dec-OO 332 1971 0 0.59 Jan-01 58 1973 0 0.59 Feb-01 0 1973 0 0.59 Mar-01 58 1975 0 0.59 Apr-01 43 1976 0 0.59 May-01 10 1976 0 0.59 Jun-01 0 1976 0 0.59 Field: Swanson River County: State: Alaska Reservoir: 62-5C Date of test: Gas (mefd): Condensate (bcpd): Water (bwpd): TEST DATA 0 0 0 RESERVOIR PARAMETERS Net Pay,ft.: 0 Porosity: 28.5% Water Saturation: 44.2% Pressure Base: Gas Gravity: N2% CO2% H2S% Condensate(Y IN) Pc: Tc: BHT,F: WHT,F: TVD(ft): Orginal BHP(psia): . Zi: Pressure Grad.(psi/ft): OGlP, MCF/AF: Avg.Yield, B/MMCF: Classification: Status: Reservoir Area, Acres: Net pay. ft.: Reservoir Volume, AF: OGIP, MMCF: Fuel & shrinkage: Recovery Factor. Ultimate Reserves Cumulative Production Remaining Reserves 14.65 0.6 .0.0% 0.0% 0.0% Y 670.98 359.26 117 76 6078 2841.0 0.83309 0.486 1453.2 0 PROVED 228 12.22 2786.16 4049 75% MMCF 8BlS 3,037 272 2,765 ./""- RESERVOIR DATA SHEET ~ Well Name: 212~27 Operator: UNOCAl Reserves as of: 1/1/98 FaultBlocR: SITP(psia): FTP(psig): bclmmcf: bw/mmcf: 0 0 0 0 Data Source Sonic porosity hds Estimate I. Pg = 0.465 PROBABLE POSSIBLE MMCF MMCF BBLS BBlS Comments: 1) Mapped to gas/water in the 34-28 . 2) Apperant perm barrier seperating the 212-27 from the 314-27, 21-27 and 12-27. These wells all took wet in this sand. mjz Attachment 6 8/4/98 Attachment 7 SRU 212-27 -- Cum Production vs P/Z plot (Last updated on 7/29/00) 4000 3500 ~ u ~ u ~ ~ -- u u y = ~1179.2x + 3456.2 ------------------------------------------------------------------------~:~-~.~~~~---------- ) 3000 ---------~-----------------------~---------------------------------------------------------------------- 2500 --------------------~-.-------------------------------------------------------------------------------- ~ .~ ~ 2000 --------------------------------~------------------------------------------------------------------------ Ñ a; 1000 ------------------------------------------------------'-------------------------------------------------- ) 1500 -------------------------------------------~----~-------------------------------------------------------- 500 -----------------------------------------------------------------~-------------------------------------- 0 0.00 ., / OGIP = 2.9 bcf I 1.00 2.00 3.00 4.00 Cum Gas Produced, bcr O:\Gas Cft\RScott\POZ_AII\212-27 Sam ,~ ~ UNOCAL8 Attachment 8 ~ ,fanson River Unit KGSF #2 Revised 3/6/02 Draft: Wellbore Schematic for Side-Track of SRU 212-27 j RKB to TBG Head= 14.32" CASING DETAIL SIZE WT GRADE TOP BOTTOM L 22" 0' 32' 9-5/8" 40 J-55 0' 3455' 5-1/2" 17 N-80 0' 7800' (original hole) 1 3-1/2" 9.2 N-80 5800' 6300' 3-1/2" SSWWS 6300' 6800' ~ L. TUBING. TAIL PIPE. and SCREEN DETAIL: 2-7/8" 6.4 L-80 0' 5800' ~2 ~ ZJ3 NO. 1. 2. 3. PROPOSED JEWELRY DETAIL Depth Item +1-2500' Methanol injection port (ID= 3.813") +1-5700' Gas Lift Mandrel +1-5800' 5-1/2" x 3 1/2" Liner hanger wi PBR /4075" window milled in 5-1/2" "",ing at 5900' 3-1/2" WWSS Screen ---------~----------------------------------_L. .~.-\ ---- m - - - - - - - - - -- - - -- - - - - - -- - - -- -- - - - -- - - - - - --, 3-1/2" blank liner cemented to liner top TD = :1:6825' MD/5243'TVD KGSF #2 Draft Schematic.doc Drawn: 03/06/02 DRAWN BY: GAD r-. ATTACHMENT 9 ,~ EG&G Chandler Engineering Model 292 STU Analyzer Test time: JUly31 00 15:26 Calibration i: 1 Test #:4 Location NO. :2540 Methane Ethane Propane i-Butane n-Butane i-Pentane n-Pentane ( C6+ ) Moisture Nitrogen (CO2) --- Standard/Dry Analysis--- Nolet BTt1* R.Den.* GJ?M** 93.482 946.38 0.5178 1.880 33.34 0.0195 1.717 43.30 0.0261 0.327 10.67 0.0066 0.463 15.13 0.OO~3 0.116 4.64 0.0029 0.111 4.46 0.0028 0.171 8.69 0.0054 0.000 0.00 0.0000 1.5GG 0.00 0.0151 0.168 0.00 0.0026 0.5028 0.4731 . 0.1071 0.1459 0.0423 0.0402 0.0737 Saturated/Wet Analysis Molet BTU* R.Den.* 91.855 929.91 0.5088 1.847 32.76 0.0192 1.687 42.54 0.0257 0.322 10.48 0.0065 0.455 14.87 0~0091 0.114 4.56 0.0028 0.109 4.38 0.0027 0.168 8.54 0.0053 ~.'40 0.88 0.0108 1.539 0.00 0.0149 0.165 0.00 0.0025 1048.9 0.6083 Total 100.00 1066.6 0.6081 1.3850 100.00 .. : Uncorrected. for.compressi~ility at SO.OF & 14.730:J?SIA. *1r: Liquid .Volume reported at 60. OF. . . Saturateâ/Wet Analysis 17.619', 0.6096 0.9975 22539. ,:Stu/lb 1051.5 Btu/CP 46.651S'lbm!1000CF Standard/D~ Analysis Molar Mass=: ~7.612 Relative Density - 0.6093 Compressibility Factor. 0.9976 aeating Value ¡¡¡ 22928. :etu/1b Heating Valu.e = 1069.1 Btu/CF ~solute Gas Density. 46.6285 lbm/10OOCr Wobbe Index . 1347.09 Unnormalized Total: 92.89S Last Calibrated with Calgas Of 1057.3'Btu/CF May 05 00 ~2;26 .' C6+ Last update: GPA 2261-90. C6+ STU/CF 5065.8, C6+ lbm/Gal 5.64250, and C6+ Mol.wt. 92.00. , ~ ,Q¡tily Operations Report Platform: Swanson River Field: Swanson River Rig: Project Objective: Drill & Complete Grass Roots Well Inlet Drilling CC#1 ~ Date: July 17, 1999, Report #: 15 Drlg Contractor: Inlet Drilling ~, Attachment 10 Well Name: SCU 2438-4 Spud Date: 7/12/99 Project: ~ days 15.0 hrs F/Spud: 5 days 2.0 hrs Current Hole Size: 6.0001ñëhes Present Depth: Drilling Hours: Footage Drilled: Average ROP: 2,553 ft 5.50 hrs 403.00 ft 73.0 ftIhr RKB Height (ft): Last BOP Test: Pressure (High): Pressure (Low): AFE#: 134703 18.10 AFE Cost: $ 1,194,973 7/16/99 Daily Cost: $ 37,721 5000 Previous Cum: $ 406,261 250 Cumulative Cst: $ 443,982 HES Comments: None Days Without Accident: 50 Safety MTGS.: Tourly meetings. Date: I Spills: 0 Spills to date: 0 I AM Drill: PM Drill: BOP 1:40 Present Operation: Casing ShoelTublng Information: Slow Pump Rates: Drill 6" Open hole Size Ibltt MD TVD LOTIPPG Pump: 1 2 Total PCB: 19 Drilling 1: Nick Scales 13 3/8" 68 96 96 SPM 44 20 76 DRLG: 2 Catering: Foreman 2: Tim Brandenburg 7" 29 2,150 2,150 15.7 Press: 425 400 Prod: - Welders: Tool Pusher: Jerry Sandige Liner: 5-112" 5-112" Rig Cont: 15 Other: 2 Strk: 9 14 - Boats: Helicopters: Depth 2,140 2,140 L.U-P From To HRS Operations Detail L 'Õ:ÕÕ""""""":f3Õ""""""':3:'30"'i=õüñifñewdrawworks brake pãdš1õ"iJë.;vããïiñg"'ü'ñ'èvenly on drillers side. Remove two pads-äñirïri'iTïíõ"ãITòw"'--""""""'" ........................ "-..................-............"........... """'-"""""'" ïiïãñi"'ïõ"¡:¡ëïë'tiãtõ¡:îïiïè face of drum. ...................................................................-...........--......,...- .. "........-.........",..--....... 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MR SCU 243B.4 07-17.99.xI5 Page 1 012 Revised:7/12I99 by MWD D8i1y Operations Report Well Name: ~, ~-----.., Date: July 17,1999 SCU 2438-4 p UNOCALe Report #: 15 Fluid T e I MW TMP I Vise I PV I yp Gels I ES YP PPG (f) sec-1 1 Oscl1 Omn Fresh Water Gell I 9 72 I 50 11 23 11 15 I Sample Lac.: Flow Line Trip units Connect. Gas: 101W1 HTHP I Cak~ I CI. 10rrecte1 3 I 6 1100 1200 1300 1600 (BHT) 32nd/ln mud WP Solids I 0 97 1 200 I 3.5 9 11 23 30 34 45 unitslMAX. Gas: units IBack GRND Gas: units Bit# 3 Size (in) 6 MF Type SEC/DBSFM2465 PDC Serial Number 5996376 Depth (ft) From To 2,150 I 2,553 Dist 403.0 Rotate Hrs 5.5 ROP (ftIhr) 73 0 D Condition L B G 0 R BHA WT Flow Press NO From To Length (kips) (gpm) (psi) Description 3 1286,43 6" PDC .......................................... ......................... ........................ ............... ........................ ....................... 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I Hours on Jars: 10.0 """""""""""""""""""""""""""""""""""""""""""""""""""'"............................................................................................................................................................................................................"""""""""""""""""""""""""""""""""""""""""""""""""...... Weight-On -Bit Drag Values: Torque Values: Average: 3 Kips PU: 52.0 Kips On: 3400 ft..lbs Maximum: 4 SO: Off: Kips 42.0 Rotating: 3 Kips Kips --¡fuT: ft-Ibs Max: Sliding: Kips 45.0 ~ ft-Ibs Top Drive Information: MD Incl. Azimuth TVD MD Incl. Azimuth TVD MD Incl. Azimuth TVD MD Incl. Azimuth TVD IRlg Equipment Down: l°tal Rig lime 8.00 hrs :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::................................=:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::...........................................................................t I§~~!t~~§;!!§:~~=~::::==~:~::~=:~~==:=~:=::=:=::~~:=~::~==:=~:::=~~~:.:~~..~.~~..~~ß~::=:==~:~:~=~::::::::::::::::::::::::::::::::::::::::::::=:::::::~~:::::::::::::::::::::::=:::::::::::::~~::::::::::::::::::::::::::::::::::::::::::::::=::~~:=I 00:00 to 06:00 Summary: Q:~9.Q:~~:Q2.:::~~!:(!E~5i::~;:~~~::!~Æ~~~:;::::!~~~§::~~M.::~..~~i~:~~\::r.~~~L~Q::ë~~p.~r!~J'.~~~:~~~~~§:~:(6~::!~:!.~Ë~}r;==:=:::===::::::::~~:=:~..~::::::::::::::::::::~~:::::::::::::~~:::~::::::::::::::::::::::=::::: 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....-....................................-............................................................... ............................................................................................................................................................................................................................................................................................................................""""""""""""""""""""""""""""""""-""""""""""""""""" ........................................................................................................."""""""""""""""""""""""""""""""""""""""""""""""""""".........................................................................-....................................................................................................................................... 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""""""""""""""""""""""""""""""""""""""""""""""""""'"""""""""""""""""""""""""""""""""""""""""""""""""""""'"................................................................................................................................................................................................................. ........................................................................................................""""""""""""""""""""""""""""""""""""""""""""""""'"....................................."............................................................""""""""""""..........................................................................."............... MR SCU 243B-4 07-17.99.xls Page 2 of 2 Revised:7/12199 by MWD r-- Attachment 11 ~ 5il{) 2ì.}~)_;-\ CUM $513,122 AFE# 126626 ACTUAL TIME 3.33 DAY AFE TIME 4.00 DAY ACCEPT RIG 8/4/97 16:00 8/7/97- DRILL FROM 2074' TO CASING POINT AT 2125'. POOH, TIGHT HOLE FROM 1331'-600'. RIH WITH CLEAN OUT ASSY. REAM THROUGH BRIDGE AT 642'-685', WASH DOWN FROM 685' TO 750'. REAM TIGHT SPOTS AT 1425'-1455',1600'-1640' AND 1877'-1925', TAG BOTTOM AT 2125' WITH NO FILL. PUMP HI VIS SWEEP WITH NO SIGNIFICANT CUTTINGS RETURN. POOH WITH NO PROBLEMS. BEGIN RUNNING 7" SURFACE CASING. SWANSON RIVER #223-28 DAY 5-7 8/8-8/10/97 D.C. $63689 CUM $712145 AFE# 126626 ACTUAL TIME 6.33 DAY AFE TIME 7.00 DAY ACCEPT RIG 8/4/97 16:00 8/8/97-RAN 7" CASING TO 2125'. CEMENT CASING WITH LEAD CEMENT OF 400 SX (140 BBLS) CLASS G WITH 4% BENTONITE, 2% CACL, AND .266% CELLOFLAKES AT 12.9 PPG, AND TAIL CEMENT OF 4 BBLS CLASS G WITH 2% CACL, .1GAUSK D-145, .75 GAUSK D- 300. PROBLEMS PUMPING TAIL SLURRY DUE TO LOSING PRIME. DISPLACE CEMENT AND BUMP PLUG. FULL CIRCULATION THROUGHOUT JOB, CEMENT CONTAMINATED MUD TO SURFACE. ND DIVERTER AND RAN 1" TUBING TO 96', PUMPED TOP JOB WITH 74 SX CLASS G CEMENT. SET SLIPS, CUT CASING AND INSTALL TUBING SPOOL. NU BOPE. 8/9/97-PRESSURE TESTED BOPE TO 5000 PSI, WITNESSED BY LOU GRIMALDI-AOGCC. RIH WITH 6' BIT, TEST 7" CASING TO 3000 PSI. DRILL FLOAT EQUIPMENT. 8/10/97-DRILL 10' OF NEW FORMATION TO 2135'. PERFORM LEAK- OFF TEST WITH 9.0 PPG MUD AT 2058' TVD. BROKE FORMATION AT 1300 PSI = 21.1 PPG EMW. DRILL 6' HOLE TO 3923'. '/'"""~" SWANSON RIVER #223-28 DAY 1 (08/04/97) D.C. $160,171 CUM $394,968 AFE# 126626 ACTUAL TIME 0.33 DAY AFE TIME 0.33 DAY ACCEPT RIG 8/4/97 .--- 16:00 8/4/97- RU POOL ARCTIC RIG #123. ACCEPT RIG @ 16:00HRS, 8/4/97. (FUNCTION TESTED DIVERTER 8/3/97). CLEAN OUT 13-3/8" CONDUCTOR WITH 12-1/4" BIT TO 86'. PREP TO DRILL AHEAD WITH 8-1/2" BIT. DAY 2 D.C. CUM AFE# ACTUAL TIME AFE TIME ACCEPT RIG 8/5/97 $32,624 $427,591 126626 1.33 DAY 1.33 DAY 8/4/97 8/6/97 16:00 8/5/97- DRILL WITH 8.5" BIT FROM 86' TO 158'. FLOW LINE PLUGGED WITH GRAVEL. CLEAN OUT AND MODIFY FLOWLINE. DRILL TO 162', KELLY HOSE FAILED, REPLACE SAME. DRILL FROM 162' TO 283'. LARGE AMOUNTS OF GRAVEL CAUSING HOLE PACK-OFF PROBLEMS AND FLOWLINE PLUGGING. SWANSON RIVER #223-28 DAY 3 W~97 D.C. $46,886 CUM $474,477 AFE# 126626 ACTUAL TIME 2.33 DAY AFE TIME 3.00 DAY ACCEPT RIG 8/4/97 8/6/97 16:00 8/6/97- DRILL WITH 8.5" BIT FROM 283' TO 2074' (KICK-OFF POINT AT 500'). SW ANSON RIVER #223-28 DAY 4 WV97 D.C. $32,006 8/7/97 0 -4307.08J",,>--CAMCO MM MANDIlÊL ',:". . ' ,. :.:.. ."i. 13.07, 'Co " ," 20 JTS,2%" EUE art! TOO. , ' ,-' , ,':, 6,19.15 "" '. ' , , ~ 0 -49J9.30'?- CA1«;~ }1M }WID~t -, :,:,: :'>:":'::"'~""': ','<~:':¡:: :~ (,,'~,:": :"'3.01 ::::IIi .. '. ' ' .' ","',,' " , ~ ;:',,' "":~':, ,', "'15,~S'2%",EUE:ard'TBG~, :'~;";"',:,,:', :'460.64 ~ ~5412.95" C~-1CO"~{UBEL"" ,...;, ',"~'>.:,:'>..,::~', ':"."'" 13.05 . 9 JTS. 2%n'~UE 'Srd TOO~:', ":',:,,':',' ,281.391 ,~ - 5707.39 r CAI.~O NH HANDP.EL ' ..' . ' .":" ' 13.06 , ::; " 9 JTS. 2%"",EÙE SrdTBG.' '..' ',"" 278../.7i \-" 7119' :' -5998.92' CA!.:CO 1.:1.-1 MA!i'DBEL ' " : .", ,0:'",...: >",,;.~,..,' ': 12.83' f'r""~-"722ar&,' ,'\..C.P.120S' ""',,.., ,,' , '" ',',::", '",.,--:::', ~/;. ';: ~ .1'" , 14S ,.rIs. ,2\" ~UE 'SrdTBG. ,.:,,:, 4605.04 "~i({~)-~:, 'Ji ~P,V,8118' ":"""",.':':" """':':',,', ft~~.' OI~1J -~ --:1Q,616.79~ 'arm'nU" SlEEVE 2\""': ',..'< """< .," 2.46 ~~~¡,:;,' 6~1J~ . ' "', ,',..",~:.:,.n~' 2%q'EUE',&.d T~. ",.',>,' :';', ',.... ,31.06 ~.¡ij~~~" " "'" '",", 'i;;~~~¿;; ;',,' ;' & 8 -10,65~~31,' B~~~ BS-16-.1 HID. ,P~ 2%~, 'x ,si" ,,' , ,,', ':' 3.9,6 :~!f:t~': . H2 ~, ~;' I~" srilJ) W,&í /I ',1172 ' , ..2 JTS. 2%11, EUE Srd TBG. <"':' ':, " ..'~ : 62.80 ~,~~~;~ :. -', . -10,717;b7' BROWII 115-16-1' Hip,. PACKER 2%",% Sì" ' ' ',' _.:' :3.94 \ ,:'::';'{202' 3 -10~2h01I" CYl':m'tlsn tlIPPI.E'~'Po::sitionllJ, ,,:"', '"",.,,:' . 1.50 ',~,..,,;¡i,~\'" {", $00.. . 2' ' " " ' B'A~~R 'DT H~T JT ," ',J'".,' .," ": ;': ',' " 20.31 !~~\'~ .. , . . :tIJ'..... ~ . , ',.. ."', " ~- i:,' ,,': : -10,742.82' BROWN "CC" Sl,-~TY J'f'..' "~,,,.:, " , ":":" ,": '., ":, .92 ~""",,::;~ . H3, : : ' ,', , 'BAr~ BLAST JT~' " ":',' ." 6.10 ,,:,,' o¡O¡;:~, ',° ,.s¿-10J~49.641 tiTIS "XA" Sl.E.EVE~" '.." :' '" " , ' " 2.86, ',~, lO~l~, -10,"52.70' - ÈRo:m }!3~16":1 HYD, 'PACKER 2%" x ~" 3.94 ' ",R I/o)sl . J.!.J~ 10,'7;6.64,' OTlS tis" ,N;rPPIE" Po::sition 'i2",,~' '..: 1.50 ~~l,q~H4' : : ,FILL lö/'i4- '- 'D4\JŒR BUST JTS~ & puP2Jå" ~, ' ',: :90' 1075'S' "" '(20.:i1')'(5.081)(15.001),(FUP 1.09') '41.48 :~: Se:"Þ --1'0,799.62: ' , ar,1S "IA" SLEEVE 2%,"":",, ',: ,', '" 2.88 ::~,;,~\.. ~\..°J'1'b-~ ~10,BO2..5?1 ST~P SUB,.,',' , " ' ',' .5? 1,'" ~~fX 10,803,00 STOP SU~ « ~~At UNITS INSm:: J.!C1D,' OF," PAC1ŒR 4.69 :;if,. ' \ D 'I~ 10,807.69' 'CAMeO "0" NIPPLE h1'urnod down colb.r) , , .9~ ,~ <! H 5 ~ ~ r: CA PwG 7f.í /0,.72 , , '~lUP.ft. 2?1I Eœ TOO. CUT .~~~F ,CN 4~o 12.1~ ~ ("' ~. . -10,820.741- Top or Tubing, ' " , , ,\ " ",5,0, -I' ,32' ~ -, " l)i/i 10847' ~'. "I- ,5tubt.'10".3:'> SRU "'1"2'-'27 ' ,~,: ",', t ',~: '-""""""", -10,89,2' , Top or P1UC: ,':" ,,',','.--' ,; , " ~~~' ",&.u~ '10988' , "".",;,..,:':..~~:,,':\:,'E.i;',,::', ::",'",: ' , :;t\' u~ .1I1.~6", CA,SING"".a:','",:,T.UB, ING DETAil, " : 66 ~~~ð ~~ u~~ ¿ ~ ~ :: :::~ :~ ::p of 1>l1J¡¡ 5 E C T~ ~,:,2 70' '8 N"R,9~; ~-" ift~ ,~ ," 'i:-'1 . "'!, ' .. 10. II) , .., II In ,.¡. It) " '¡ ~;.:l, ': I , \.... ,4' 0 ~:~ ' ' ~ ' i:~:, ~ ~,~!#)(\:~;: ;' '~"~";;';"", tå:,,¡;. '.. i ~"'" . ;;,' "" f~~" "4037' þ"l,:;,' ~'! ' '.. . ,¡,,; ~"':,', 2736' - AI;. ~;; ï:J '.,"<~, 0 0 , ~ '..~... , co co ~~:'¡~'i';:' ~ ~ 'l!o."'~"" ~ ~'; : :::,~"': ~ . 0 ~.,~J¡¡:o¡,"- J: <It f. ;:~;~:,;;,,::; '~ '\;".¡" , . ~, " ~;;~:~~:;:::; ~ ,: .. KB. 191' A~chment 12 ,. -" , 5 I t O~'. .' , ....... '~I '.... 176 Y.-.B..:'O TUBTIlG }WlGER 21 J):~ ¡ , TUBI!:~ HlJJGER . ~~ : ,. . X-G'/?uP JT. (,o.l8'~ ~ JTS. 2%" EUE TI3G.19}:~,~1 , ~ 221.;5'-')- GTI.S BALL VALVE ' , " ' 0 C "I"t :;¡ . '" I t "'D.V, IO/S' 53 JTS. '2%" EUE 8rd TDG. '""' , ,G,j'].4'l; Q - 1864.09'l- CAl,:CO }.i-1 M.UID~L '. ' . " 13.06 , ' ;:l " . " 46 JTS. 2%. EUE Brei TOO. 0' '. ,.' '. 1424.t;,9' '", 2943 , . .,', ' 0 : -3:301.64'~ CA!':CO 1,:1 JI./iIIDREL ,," '",' 0 ",' '."" 13.1S! . , 0:. ' 32 JTS. 2%" EuE Brei TBa. ' " 992.29 , ,. /"-- Mr. J. B. Hundley Drilling started: Drilling completed: Well completed: Total Depth: Casing record: Junk: Attachment 13 /""', COMPOOION DATA (NEW WELL) SWANSON RIVER UNIT NO. 12-27 - AIASro\ U. S. L. Anchorage 02èS4Q6 July 4, 1959 Drilled by Mountain States Drilling Co. (Standard Oil Co. - Operator) November 6, 1959 November 30,1959 11500', plugged 11492' -11396' and 10986' -10892' (bridge plug @lO986') 20" conductor cemented at 30'. 13-3/811 54.5# J-55 casing cemented at 2943', stage collar at 1019'.;ð¡q / 9-5/8" 40/1: N-80 casing cemented at 7228', top at 2736' . 5-1/2" 23, 20, 17# N-80 casing cemented at 11492', . stage collar at 8178'. Jet perforated with 4 -t" holes per foot 11165' -1ll55', 10832' -10810' , 10790'-10760', 10750'-10726' and re-jet per- forated 10830'-10822' Sidetracked hole 3444' -7622'. Plugged 7279' -7020' , 6755' -6590:1:', 6255'-6060:1:, 5778' -5470:1:' , 3630' -3344'. Following cemented and abandoned in sidetracked hole: Fish #1: 3642'-7601' consisting of 10-5/8" bit on 9 - 7-3/4" O.D. D.C. 's on 117 jts. of 4t" drill pipe on stub 4t" drill pipe. Per- fórated 6~" J.H.P.F. 7279'-7280', 7274'- 7279' and 5-t" J.H.P.F. 7150'-7155'. Per- forations 7279'-7155' squeezed with total 485 sacks cement. Perforated 5-t" J.H.P.F. 6755'-6750' and squeezed with 100 sacks cement. Perforated 5-i" J.H. P. F. 6255 t -6250' and squeezed with fP5 sacks cement. Perforated 5-i" J.H.P.F. 5778'-5773' and s~ueezed with 150 sacks cement. Perforated 5-2'" J.H.P.F. 5254' -5249~ ! - ~885' -4880', 4668' -11663', 4660'- 4655' and 4400' -4395' (could not break down all perforations below 28001/=). . Fish:/l2: 3515 t -3903' consisting of lot" washover shoe on 387' x 7-5/811 washover pipe. /~- ~, cO!œIZTIO¡;¡ REPORT ?e.ge 4. ~; W-~I¡~O: RIVER UN7.':: 12-27 Jection 27) T. 8 N., R. ) w., :e,~rd 3~1 ':T.-~1DA...~ OIL CO. OF C,A1IroIUiIIA, OPERATOR July 121 1959, cont'd. CeroentiIl!$ Detail FirGt (..age: ~tlxed 1000 GC,X pen:nnente construction type ce¡:¡ent in 73 mn to averaGe 115 pet slurry. Took 13 mn to inGert top l'lug. Di:3plD.ced cec w/445 bbl mud using rig pump. 2uL"'þed plL.~ in 33 mn.: 1500 pe1. HOV¡CO ceœntinc truck took over from rig puz;rp aß pll.C bumped. Ce::l in place 3:49 MI. Used one top and one 'oottOtl rubber pluS. :'ccond -tac;e: DropJ::1od TN open1nö pluG. Ports opened after 16 mn. Circulated 1(3 :dn. :.!ixed 1000 ¡jaJ< FertJa.Uente conat..:'1...:.ction t~'þe cct:lent in 79 ¡::¡in to average 115 pcI' ::;lllrry. Took 15 miD to insert top plttg. Displaced thru TN ports .. lOla' v /160 bbl ~d using riG pump. 3umped plug in 13 mn r: 1500 })ci. HOWCO cemt'.3 truck took over ¡'rom rlS puap as plug bumped. Cem in place ,-; 11:11 AM. Used one top rubber plug. Full circulation throuLllout ce¡¡¡t' 6. Good cem returns on cecond ::;tage. Evidence of channelinG on firot Gta3"e (JODe clabbered com to surface during mixing of 2nd ste.C;:e Gem follm..red by :nud priOl.~ to appearance of :::.econd Sts.b~ ccm dt~ring second staf.;'e displacement). Ca[;ing Detail All 71 jts 2914.19 13-3/3", 54.57;;, J-55, R-3, SR, f)T~, new, Hational Tube, J"-:L, A.O.::l:1ith, :te\J8.rts c~ Lloyd.:3 , etal. Cem. E~uip. 5-33 HOi~"CO Guide fhoe, Belter Differential fill-up collar one jt. up, baffle p13te 2nd collar above Ghoe, EOHCO rN cultiple staGe ceœnter (- 1017 -lCl] , . landed belo\-1 KB Ceüented .... 2919. 52 23.33 2943.40 10' cellar Casing is eq~ipDed v/S cent~llizers: (1) 5' above çhoe, (2) 5' below fill-up collar, (3) over 2nd colla~, (4) over 3rd collar, (5) over 4th collar, (6) over 5th collar, ('7) 5' balm; TN collar and (:3) 5' above DV collar. /~, ~, CO!~rÆTION REPORT ;',JAlT:ON RIVER TrITT 12-27 ~ +1 '"'7"" r:J '" R 9 '! ,- d "'~.u ;.cc" on t.., ) .1-. U ~.., . ""1 .ewar, .tX:~,¡ ;:'£p..I'rDARD OIL CO. OF CALIFOfu"UA, OPEJA1'Œ\ Page 5. Jul.y 13-15, 1959 ¡~a.de up 13- 3/8'! casing head. InGtalled field welded spacer spool between eGg. bead and BOPE. Applied lbæ ~si to test JOPE. Held OK fer 26 mn, then lower flan,';e': weld failed on spacer npool. Rewelded fls,l1€;e and reinDtalled BOPE. JaPE tested at 1550 psi fo~ 50 Ldn - OK. .T1.;l;f 16, 1959 f Cleaned out to 10' belaY £'11141' collar. fo::- 30 min OK. Drilled 12-3...11 hole ... Tested BOPE and caGing :" 1550 psi <7f- 73} pc£' 3000' 3387' 387 ' drilled July 17-28,1959 Drilled 12-k" bole 75 pet 3387' 3¿~59 ' 72' drilled Drilled 11-3/4" hole 70-73 pef 3459' 3915 ' 456' drilled Drilled 11" hole 70-76 pct 3915' - 4Q15 1 lOC 1 drilled Drilled 10.5/3" hole 72-85 per ~151 - 7613' 3598' drilled J'.lly 29, 1959 Drilled 10-5/8" hole 80 pct 7613 ' - 7622' 9' dl"i11ed .7tuck IP :; 76011. Encountered sudden increaGe in pit level, mud in hole started kicking at apþX'Ox. 12 :15 i~"l. Pulled off botton 21' before pipe Ðtuck. C1oced 3OPE in apl1ro.x. 10 mill at't:,er cto.rt of mud acti'lity. Dled off gtr:. thru choke line from annulus in 30 mn '<rhi1e puJ:I:)ing approx. 350 bbls Go pet mud thru DP. ,r-'. ~ CœPLETION REPORT S¡'l.l\1!Smr RIVER UNIT 12-27 . ~:ect:!.on 27,~. 8 ~' R. 9 ~:., Sewrd ,B?:l'~ ~-:I:A:J1~-m OX'1 co. Oi CA'l..r,e"oæUA, OP'.L.:2.A.',¡,Ì()H Page 18. r:epter:lber 3J, 1359, cont'd. Ce~, 9-5/GI~ X 13-3JFY' la1?- @ Z{36' w/?-oo sax. Epotted 23 'obIs wate::- th...-u open ended D? . ~?:(37'. Pulled. uJt to 2593'. nixed ¿Of) ~a.x Per!JB.:lentc construct:!.on t;:,'l'>e ceIn w/c$ calcium ch1.oride added to ave. U8-120 pcr slun~.. Eqlu:J.:!1ized cez:¡" puUed uIJ to 2016'. CIQ~ed BOPE. DiGþ1 caIn '17/38 Dbl ::XUe.. ~'lo:ddnG pre;:¡~:'l'e 50C psi. Wd.ited 25 L11n. 3qtleezed 9-J bbl !:IUd by hesitation method. .Pinal ¡'lO::~king pre::;8"..~--e 2000 1'3i. CeIn in place 12:15 ?r,!. R~_'1 in ':¡íJ2~f bit, located cem stringer:> "~ 2535. CO Goit oem to 2583'. Octobe2::. 1, 1959 CO sort cem UíUf¡" bit -1:;0 2620', bard oem 2620'-2736'. Pressure tested lap ::J. t 2~.:OC> 1.\6:1 ¡'or 3() min - Œ~. Ra.n in ¡-r /&~" '01 t. DO CC1ll 2736 I -2758'. DO float collar. Ran to shoe o'f ~/-5/3:t ,~: Y2¿ö'. no oem. Clo::-.ed BOPE, :pl"e!;~J".:l"'e tooted csg. wíJ.6o0 ::;si - OK. ~ober 2, 195~ schlumberöer jet perf'd 5 - .}" l1oleö in 9-5/8" linsr .~€ '7f.:oßf. Squ.ee;~e.d PeI""Zs .,: 7208' ...:jJ:JÜ sæ..:. ~ ROweD ret:'ieyable œm retainer .~ 7137' . For-::e.tivn ;jroke down under ~)OO psi. Preceded cet:!. ¡'1/20 bbl ,rete::.'. Hi:~ed 100 :~a:,; Pe::."t1i.U1C::llte CO%19t::'t:ction type cea to :i..13 pcf s.lurr.f. DiqÙ v/5 obi ~ta.tc'::' i.'o11ov.red by 95 bbl !:md. Fiœl ~1O1'ld!l~ :';::~~.Sllre 2900 j)ci. Back Gc't'tt1ed ~?pro=:. 3 Ga:~ oem. E~;t. 12 bþ1 oem thr-tl perf. In place ~.: 15 :PM. 1 11,: 15 crill r.ù;dIJß and D~.ing into place. èktcb~,: 3-)+1 1?J59 Drilled ô~rl hole )1-95 pef 7230 7590 270 t d:d::led October 5, 1959 Ddlled 7-5/f:/' hole, 95 pc!' 7500 7650 150' \Ì¡,"illed ~?1?~~' G, 1)5~' Re.n Schlun'berser I-EC 1°13, '7227' -765C r, mcro-cali¡,cl' loG 723l-{b55', sonic log 722'7-'765;; I . ,/~ /--..., COMPtSTIOlf R8PO.RT SWANSON RIVER UNIT 12..27 Section Z7, T. 8 li., R. 9 w., :':'ew.rd B&ì:; anriDARD OIL CO. OF CALIFOR!1IA, OPERATOR PaGe 17. September 28, 195~, Reaued aud conditioned hole 62)C-723C'. f~tember 29, 1959 C~nted- 9-5/3." liner C 7220' \¡/t°"R 0' 2736'.- After failure of loot col1a.r located 2 jts above siloe \i'hile l"Unning in hole, iru,-talleu. ",<;;Cou.\1 .:1oa,t collar top of joiIJ,t lu4, 35' bel';)l¡h~':16er. Used E'ù.¡:-ns ;;lain liner hal-¡ger groovedt:or cementing 'witll -¿-)/411 hole::> telon clip~. î-œ.n vn l"1.t DP v/l Jt 2-7/cY' tùbing stinGer to ;.;wab Cu? a3G;¡. inside )-5/Ú" c~C. nung liuc;: 2 ft. off botto~ ~, 722J'. ' Cementing De'tail Mixe:d 509 so.;; perœ.nente constl"\;.ction t:r~ ccr:>. to e.vg. 116 pcf slur:::") in 45 min W/HO1K:,C; cem tj,'~,ck., P~'eceded CCIn w/2G òbl Hater. Dis¡;l. cem ¡:/J.J.:¿- bb1 water i'ollo~¡ed by 361',1 D'ol )4 pc! mud in 65 min. Theoretical d:!spl. to 100' above shoe v7/n~ comp. allowance. Full ret'....l'IlG t::...T\lCut job. In place l: 50 l'i'¡. Final \'lOrlúng :tJI'eoc. lOCO :psi. Liner Detail All 1()6 jts 4484.97' 9-5/8", 4cr/#, H-Go, R-3, SR, L~:£, new, S?ang Cenl E'l1.lÌp, & Banger 7. ¡row~O guide choe; IIOHCO i'1c'at co11~r . top of jt :/:'2, 71)4.2'; HmfCO float col]ß,r , top 01' jt £104, 26:;1'. 3u:-nc. :ç.lain linel' ho.Jlb':er --- Hangel~ ,~ 4492' 2736' Bcttom ' '7223' Line:- i5 eq1.Ù.þped vi/9 centralUzc.r.'E on top of' jtc 1, ~" ¿jo, 5, G, 101, 102, 103, 105. Septcmbc::- 30, 1959 P.--essure tested. ')-5/2/1 X 13-3/3" le.? Took l~d C' 8 1,)1);'1 U/500 "J:Ji. w, - /~, ~ COMPIETIO~1 REPORT ~1SO!T RIVER UNIT 12-27 Section 27, T. 8 N., R. 9 \v., r-eward~.t Novembe:- '7, 1959 Page 210 Ban ~_:chlumberser sonic loG, 7228'-11,424'; diplœter 7,228' -11,424'. November 0, 1959 . Circulated and conditioned. 1:>..---'1 PH'1' ::;.,'", C""" n~-y "'2 U!6' November 9, 1959 Cemented 5-'1" caB. -~; 11,4.92' in t~.¡o sta.~s. 1st Staß6 - Preceded oem w/30bbls water. Ui;ced 600 sax Permanente com;truction t:n?C oem w/O. 'J1, HR.4 retarder added in 30 min V/HOWCO oem truck. Dis:p1e.ced cem in 27 min using r1ó pump. Butq)ed plug ii/2000 psi. In :pleee 6:05 AM. 2nd ~tage - D!'O)'ped TN opening 'bomb. Cir<:. thru D'{ collar ~? 8178 for 4-1- brao Preceded cem ¡:;/10 bbls 1vater. Hi::ed 750 sax Perm.. conctruction type cern - . T,7/~ HR-4 retarder added to e.'Tfg. 118 pef slt:.l*rJ w/'fiOì~'CO oem t.::-uck. Displ.- oem w/rts punp in 18 min. Closed DV ports w/3000 psi. Oem in place 8:15 ~. Casing Detail Bottom 24 jÚ¡ 1918.45 Next 1 Jt 13.67 " 79 jts 3334.14 " 90 jts 3082.12 Top 95 jts 4039.81 CCI:1. Equip. 7.14 Total Abo'.re KB landed at Cut ?; reco'Tel--ed In hole 289 jts 11,495.33 3.52 li,491.Ôl 21~. 58 11,467.23 5-}rI, 25/f, u-80, R-3, 8 R, LT&.>C, new, Youngstown pup jt, AB ::;.1.11 ? ?/J.. AB ;:-' , "-.JIÎ, 5'~II, 17#, AB ~ <r II 2'lJ!. ft ~ 7¡f, vrr , .i1.iJ includes HOIiCo float oboe, I:IOHCO float collar on top of first. jt, :i:IOiiCO selt' fil1u.p collar on top or r.econd jt, HOiiCO DV ceæntinG collar'" 3173'. 10' cellar Casing equipped w/22 Ualli'burton centrallizers: '2 on shoe joint, 1 on second jt, 1 on collar I"" top of joints 3 thru 19 and on collar above and Delo.." TN collar. Baker rec1procatiIlß Gcre.tchers at 10' 1nter'\,'als 10" '700-10,370 and 11,110-11,240; also adjacent to cent1.'!3.l1izer!: i' DV c,ollar. Schlum'be-rger temp. surv"ey indi'co.ted top of second sJ,ta.ce ce1:l ;,~. 5410'. \ ,! ,/""" Attachment 14 ~ TUBING PERFORATIONS 11.110'-11.115 PERFORATIONS 320'-324' 5.1/2" BRIDGF PLUG @ 404' a... 20" @ 30' SRU 314-27 Final JUNE 1992 Circulate 5-1I2I1x7-5/811 Annulus Perforations 150'.155' DV @ 979' 13-3/8" @ 2883' TUBING CUT @ 3072' Note: All measurements are KB reference Original GL to KB is 15' 113.5 PPG MUD I Perfs 7750'-7755' / I 8,945' KINLEY BUTTON (LEAKING) CA' C TOC 10.530' 11,047 CAMCO M M MANDREL 2-3/8" RETAINER @ 11.100' 11,103 BROWN PACKER PERFORATIONS 11,146'-11,176' 2-3/8" RETAINER @ 11.176' 11,156' CAMCO M M MANDREL 11,173' BROWN CC SAFETY JOINT 11,178' BROWN PACKER 11,212' OTIS S NIPPLE TUBING PERFORATIONS 11,185'-11,190' PERFORATIONS 11,184'-11,246' , - , ,... '- 11,225CAMCO M M MANDREL , , 11,242' CAMCO D NIPPLE CA-2 PLUG SET 6/3/88 ~ . 11,246' BAKER PACKER """-- , - ~ FILL IN TUBING @ 11,260' """-- , ..,- ~ , , 11,431' PBTD PERFORATIONS 11,256'-11,290' 2-3/8" TUBING @ 11,282' --..,.. =~ , --... --'- 5.1/2" LINER @ 11,436' 07/08/92 ARCO ALASKA INC. WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: OS/21/92 ( TD: 0 PB:11242 OS/22/92 ( TD: 0 PB:11242 OS/25/92 ( TD: 0 PB: 11242 OS/26/92 ( TD: 0 PB:11176 ,'--" Attachment 15 ~ DAILY OPERATIONS 314-27 KENAI SWANSON RIVER SWANSON RIVER ACCEPT: 05/30/92 06:05 SPUD: RELEASE: 06/04/92 06:06 OPERATION: DRLG RIG: NONE WO/C RIG: ROLLN RIG 5 50-133-10154 1) 2) 3) 4) R/U ATLAS WIRELINE n@11434' MW: 0.0 RU SLICKLINE & PRESS TEST LUBE. RIH W/ 1.85 GR. SCRAPED TBG F/ 10980 TO D NIPPLE AT 11222 WLM. RD SLICKLINE. BLOW DWN TBG PRESS FROM 1250 TO 0 PSI. FILL TBG W/ 70 BBLS FRESH H2O. PRESS TBG TO 400 PSI - 5.5 PC WENT TO 300 PSI. PC = 100 PSI. SC = 100 PSI. BLED TO 0 AND SD. "@11434' MW: 0.0 R/U ATLAS WIRELINE. RIH W/CCL & 1-11/16n HOLLOW CARRIER PERF CHARGE. PERF'D INTERVAL F/11185'-11,190' WITH 4 SPF. POH. RIH W/BAKER 2-3/8n CMT RETAINER. SET RETAINER @ 11, 176'. POH. R/D WIRELINE. / n@11434' MW: 0.0 RU ARTIC RECOIL & HALIBURTON. PRESS TEST LINE TO 3000 PSI. RIH. HUNG UP ON CAMCO MM MANDREL @ 11047. STINGER FOR CMT RETAINER SLIDING INTO POCKET. POH. WAIT ON WIRELINE. RU WIRELINE. PRESS TEST LUBE. RIH W/ 1. 5" MCMURRY DUMMY & RA LATCH. FOUND POCKET @ 11036 BUT WOULD NOT SET. POH. RIH wI L KICKOVER TOOL & 1.5n IMPRESSION BLOCK. SHOWED GLM POCKET TO BE EMPTY. RIH W/ L KICKOVER TOOL & 1.5n DUMMY W/ RA LATCH. SET DUMMY AND POH. RD. n@11434' MW: 0.0 RU ARCTIC RECOIL. PUMPED 10 BBLS H2O, CHECKED FOR FLUID TO SURFACE - WELL ON VACUUM. PT SURFACE LINES TO 3000 PSI. RIH W/ COILED TBG TO CMT RETAINER @ 11166 CTM. STABBED INTO RETAINER. PMP DOWN CT W/ 2000# SET ON RETAINER. ESTABLISHED INJ RATE OF .666 BBL/MIN @ 3000 PSI. MIXED 20 SX CLASS G CMT. PMP 4 BBLS CMT + 10 BBLS H2O & STAB INTO RETAINER. PMP 12 BBLS H2O @ .5 BPM AND 2500 PSI PRESS INC. 2900 PSI W/ CMT @ PERFS. CIP 1245 HRS. UNSTING FROM RETAINER & FLUSH ANN W/ 43 BBLS H2O. GOT RETURNS. POH. RD. RU ATLAS WL. RIH WI 2.365 TBG WI 4 SPF FIll, 110-11115. POH. RIH W/ 2.365 CMT RETAINER & SET @ 11100. POH, RD. 1"""', ~ WELL: 314-27 OPERATION: RIG: ROLLN RIG 5 OS/27/92 ( TD: 0 PB:11166 5) OS/28/92 ( TD: 0 PB: 11009 6) OS/29/92 ( TD: 0 PB: 7780 7) 05/30/92 ( TD: 0 PB: 7780 8) 05/31/92 ( TD: 0 PB: 7780 9) 06/01/92 ( 10) TD: 0 PB: 7780 PAGE: 2 n@11434' MW: 0.0 RU ARCTIC RECOIL.PT SURF LINES TO 4000 PSI. RIH W/ COILED TBG TO CMT RETAINER @ 11086. ESTABLISH INJ RATE OF 1 BPM @ 3000 PSI. PUMP 5 BBLS CMT AND 10 BBLS H2O, STAB INTO RETAINER. PUMP 13 BBL H2O, 1 BPM. PRESS WENT TO 4000 PSI wi CMT @ PERFS. FLUSH ANN WI 48 BBL H2O. CMT RETURNS W/ 20 BBLS H2O. PRESS AT 7.625" ANN WENT TO 2500 PSI, PRESS AT 5.5 ANN WENT TO 2100 PSI. POH, RD. PRESS AT 5.5 ANN WENT TO 250 PSI. RU ATLAS WIRELINE. RIH W/ 1 11/16n PERF GUN. PERF TBG F/11068 TO 11073. TAG CMT @ 11083. POH. RIH W/ 2.325 CMT RETAINER TO 11030. POH, RD. BLED 7.625 ANN TO 500 PSI, 5.5 ANN TO 0 PSI. "@11434' MW: 0.0 RU ARCTIC RECOIL AND HOWCO. RIH W/ COILED TBG TO CMT RETAINER @ 11009 CTM. STAB RETAINER. ESTABLISH CIRC RATE OF 1 BPM @ 3500 PSI IN 5.5 ANN. CIRC 20 BBL H2O @ 1.5 BPM AND 4800 PSI. RETURNS CUT Wi CRUDE. PMP 11 BBL CMT + 17 BBL H2O @ 1 BPM AND 3200 PSI. POH wi CTU TO 10300. CIP 10:35. FLUSH wi 37 BBL H2O. FULL RETURNS. POH, RD. PRESS REDUCED TO 0 BUT SC TO 250 PSI. I "@11434' MW: 0.0 RU ATLAS WIRELINE. RIH W/ 1 11/16 PERF GUNS. TAG CMT STRINGERS @ 7730 TO 7780+(CALC TOC @ 10,530'). JOE DYGAS APPROVED ORIGINAL WELL PLAN MODIFICATION. POH. RIH Wi NEW 1 11/16 PERF GUNSS. PERF 2.375 TBG W/ 4SPF FROM 7750-7755 CIRC 13.5 PPG MUD TO SURFACE. POH. RID. SET PRESS VALVE, SEC WELL. ACCEPTING RIGI NU BOP ACCEPT AND R/u ROLL'N 5. n@11434' MW: 0.0 REPAIR MUD PUMP n@11434' MW: 0.0 R/U WATER LINE TO MIX MUD. N/D TREE. N/u EXTENSION SPOOL AND MUD CROSS. N/U PIPE RAMS 2. 375n AND ANNULAR PREVENTER. N/U KILL LINE AND CHOKE. PULL BPV AND SET CV. TEST BOP, MUD PUMP LEAKING. REPAIR MUD PUMP. TEST BOP n@11434' MW: 0.0 TEST BOP, RAMS, LINES, HYDRILL, CHOKE MANIFOLD, MUD MANIFOLD. MIX MUD TO 13.5 PPG. Rlu ATLAS WIRELINE. RIH AND CUT 2 7/8n TBG @ 3072. POOH, LID 98 JTS 2 3/8n TBG. NO CORROSION. CHANGE TO 2 7/8 RAMS. TEST PIPE RAM DOOR TO 1000 PSI. M/U BRIDGE PLUG, TIH. CONlNUE TIH W/2-7/8n DP. SET 5-1/2n HALLIBURTON EZDRILL BP @ 2987. PRESS TEST 5-1/2n CSG TO 1500 PSI (TEST GOOD) POOH W/2-7/8n DP. ."-"'" ~ WELL: 314-27 OPERATION: RIG: ROLLN RIG 5 06/02/92 ( 11) TD: 0 PB: 2350 06/03/92 ( 12) TD: 0 PB: 0 06/04/92 ( 13) TD: 0 PB: 0 06/13/92 ( 14) TD: 0 PB: 0 PAGE: 3 WOC/COND MUD "@11434' MW: 0.0 POOH wi 2 7/8 DP. LID 6 JTS. MIX MUD TO 13.5 PPG. RIU ATLAS WL. RIH wi PERF GUN. PERF 5.5 AND 7.625 CSG wi 4 SPF FI 2850-2854. POOH. RID WL. ESTABLISH INJ RATE OF 2 BPM @ 800 PSI. MU 5.5 HALIBURTON BRIDGE PLUG. TIH. SET PLUG AT 2794'. Rlu HALIBURTON AND PUMP CMT. PUMP CMT JOB AS FOLLOWS: 5 BBL WATER, 300 SX CLASS G CMT W/.15% HALAD 344 + .2% CFR3 + 1% CACL, 61 BBL SLURRY MIXED @ 15.8 PPG. SPOT 50 SX(10BBL)CMT ON TOP OF CMT RETAINER. EST TOC @ 2350'. POOH. WOC-MUD CMT CONTAMINATED INSIDE DP. REVERSE CIRC & COND MUD @ 2000'. CONTINUE POOH AFTER COND MUD. "@11434' MW: 0.0 CIRC AND COND MUD. plu BIT AND BIT SUB. RIH W 2.875 DP. TAG CMT @ 2296' wi 5000i. pOH. LID 6 JTS DP. PMP DRY JOB. POH. LID 2.875 DP. p/u HOWCO BRIDGE PLUG. RIH AND SET AT 404'. pOH AND LID DP. RlU ATLAS WL. RIH, PERF F/320-324' wi 4 SpF. POH. ATTEMPT TO CIRC DOWN 5-1/2" LINER. PRESS UP TO 2000 PSI. UNABLE TO CIRC UP 7.625 CSG. RIU ATLAS WL. RIH, PERF FI 150-155 wi 4 SPF. POH. EST CIRC THRU PERFS 2 BPM, 200 PSI. PMp CMT. MIXED & PUMPED 7 BBLS CLASS G CMT + CFR3 + HALAD 344 + CACL @ 15.8 ppG. HAD GOOD CMT RETURNS TO SURFACE. CIp 18:30 HRS. DRAIN AND WASH BOP'S. NID BOP AND LID DERRICK WHILE MIX MUD FOR SRU 21-15 P+A. RIG RELEASE "@11434' MW: 0.0 MIX 415 BBL 13.0 ppG MUD FOR SRU 21-15 p+A. CLEAN MUD PITS. RELEASE RIG. "@11434' MW: 0.0 DIG OUT CELLARS ON BOTH WELLS W/BACKHOE.HAUL CMT CELLAR WALLS TO KENAI BOROUGH LAND FILL. HAUL OIL CONTAMINATED SOIL TO SWANSON RIVER SOLID WASTE DISPOSAL pTI. WELD P & A MARKER POST & BACK FILL HOLE W/GRAVEL. SIG~TU~: (dri~~P~1 DATE: 7/9/9'-- -"'- ---,--,----____,_h - ... .- -.. --",----"- --.,-.. /~'( Attachment 16 /""" (' DAILY PROGRESS OF DRILLING WELLS iPro-S62 \ " ( '7v Drilling Oays-J WELL NO IL/-;t. '7 . 1Dbo('-;~! , . .DEPTfI AIT NO, CONTRACTOR OR UNIT ¿??t~ '. ,J-fA ,f-;.. // ... c. ';1'- ¿;J.. tJ"'- 11 SIZE MAltE AND TYPE ".,~ '\ FROM ". TII Fl ".IN JlRS, WT. ON BIT TONS SPEED DRILL COLLARS . . CASINP , ": ~I J.3n SIZE AT ,;)!tÝB I FORMATION' # SEC WEIGHT VISCOSITY cc n~ . ~ , DnLG. FLUID TY,PE WATER LOSS FILTER CAKE SAND % SALT HOLE I SIZES ,.' " lc>ù' lo \" oJ ~'\~. :";:-l , , . Ie. \ 'Ï '-> ~ ,oJ D'" SURVEY b\" .. DETA!L:Cemented 7 5/8 casing at 10619 in two stages. Ran 274 joints 7 5/8 casing incluif'n ,. top 16 joints 605 ft. P 110 LT&C 29.7# 8 ro:wp.,tp.read.. Next 152 joints 6170 ft. N 80 ::{ ';>9.7# r,rPi/^C A 1"()U110 t.nY'@.FI.cÌa 'Rottom '05 j01nt~'P-,,0 ';>9-7# Tn'p",c R ,..011110 tl1Y'PF!cL . Total casing length 10651 includes DV collar and float equipment. Landed casing at 10620 bclo'il' KB. C3.6ing oquip-ped:.wi th 3.cccssorie:s 3.8 follovlE: Shoe joint includes . Halliburton float shoe, Halliburton self' fill differential collar at top of shoe joint. .7 bl.õj.'c¡.t.dlt::c.'Ô .LJbl.õl::ù' at. 8089 :-:- 8048 - J3009 - 7975 ~ 7934 - 7901 - 78(;5 Cl.uù, 7025. 25 . centralizers placed on each of bottom 25 joints. CEMENTING,'.DETAIL: First Stage: ".' :.ConcutJ.on mud. ror 3 hours. .t;'umped 4u' bbJ.S water al1ead. Mixed ,uu saCKS construqt1on . ::\;';':'cement with .310 HR-4 retarder in 40 minutes. Di~J?laced cement with rig pump in 49 min. .:,-;:r!,;",Bttm.ped plug final pressurë1800 p.s.i. DispladfdI pressure 1000 p.s.1. Second Stage: .:\;.-;";,"Dropped DV °'P~ning bomp. DV collar opened after 58 min. Circulated and conditioned' '~;"'>':¡:\:"mud through DV collar at 8118. Pumped 30 bbls. of water ahead. Mixed 1200 sacks ;g~r:;:;;'t'on!')tr\)t't;Ql'\ C'~m~nt w;t1" HR-'I retarder in 1 hr. 33 min. Displaced with rig pump in "":.;-;t',:-,:.,33'lilin. Closed DV collar with 2100 p.s.1. Second Stage Cement in place @ 3:57 PM. .Use ,::}~,:::,;<'. Ha.lliburton equipment. Good circulation throughout both stagcl3. Final indicated casing . ..:{~.j'~:ightl~ Landecl casing in the.as cemented position. . " :," '..;. . '.. MORtliNG TOUR: . Ran Schlumberger temperature survey. Survey would not go below 4920. No ind1 ~A.tion of' A~' Fl.'" I".pmp11+'. T11F~t8" 1 -ne; tul-þl 'hPRn f1.11rì :ROPR. ,¡r-. ~ '. -.,. .< " . . . . . ...',-.'., ""'. ..... '..'. fOREMAN . ---- ----- -- ----'----------' -- -------. -... ---,,- ~ ( ~(. DAILY PROGRESS OF DRILLING WELLS Pro-S62 ! (I ìc Drilliol Day~ WELL NO. ,tJ.-Ll CONTRACTOR OR UNIT M 1- /-J ~TA-TE';"'" l(.. - Lt1 191 DEPTN I O~ 1<1 BIT NO 7 '2- " ~;;"I "'- SIZE H -tJ ~ I{-C.:s. ow $ MAKE AND nPE .. í " FRO~ FT. TO FT. FT.m HRS- TONS WT. ON BIT SPEED DRILL COLLARS CASINP'1'~ AT Ib fe:, 1. b FORMATION nPE c¡~ # WEIGHT SEC CC IN % DRLG. FLUID VISCOSITY WATER LOSS FILTER CAKE SAND SALT HOLE SIZES I SURVEY DETAlb þn, L D '?\_V rr-s- ) py c... 0 LL. ("-(t.. --- ! (, ~~d..) ~ C ¡.¡ 1..._1.) I'A ~: fA p .c;U(t. ve.- \..., t..JJcv ~-O l-J 'o"'r' ~-O' ç)E:.-e Pf:.: "- .J-.j 0 f ).J b t LA,-í \ 0 t.J D F A-» t--J V U\-(l.. (~M. G-...JJ¡- I t-...,J ~ TAt.L r' (J 6'0 fe- IT::''STë:. Ð ( Î..O D F'<; I f) é Ll-9 2,,0 . I I' f t ctc~- P \J P '~ í~, \~E::-I-L- \ f'( ere-t,O h -~-}~-,~t D C (l.(A-ft\ 5 f\ (fCf ,.J Cs- Up 3 ~...II DP MORNING TOUR: ~"5T~D ~ 'r;lt (2.-l~--,,^-~ , ,,'(-:S TT--f) 11 't' Ð ð7 t ~ (C\- tç- 1) (t c-lj ? L-tl tJ- c:;; ~ D V I T-~"T~~ P D V t.O t--t...J~ ,(L. - l '"2-00 p~ ( II 'Dl, l f L' S, f b -- e, f B t 2-Ð-o f'S ( , a tC- -- • � `.. ; � �! r � r . -�, v SAS/NG �` %UB /N!a' DET,q /L _ I V v •- 0 V v •- 0 VkCOdwp�E�Cd 2Puo✓/s.2�'Tiib.rg-7gS' ��'' ri�ICCC � r • 4S ✓/s tie-/�biiry - /42L/S' , PAL 2a , �ao..es ' . Cdwco i1>i3>iL/aird�e/Ass�mb/y wilh RO l�o�/ram-/299• . ,�c� � em21fC-I170-I/y roar • � I C'airrco ,ti.��/arrd/•r,/ Asscln6/y .r,Yh.Qa v�/,•r - /.io/ b p _ �( �r s! s• cainc�o 4,10 !lax/.e/ 4s5e"*'A y - .�� ✓/s 2 i � 1164,7g -Info. /j� S �orT. 527?.SO' C'ainco .Nti1/l,�i�dra/ Ariem6/y --1h RO i�d/rem-I.JOS•'-s 71 cam''?�• _ �d�17C0 �/if>�d110IvI //SS�T6Iy lril/! /P.� rd/I'C •/3.017' 26 Ms. 2 A -I -1,.6h7g -62/. SO' - 1UG1.49' p _ Caorc� /1>h/,f?aad��i.9ss«6 y with POvdIva-/�2Gb ; S -� ` "r— ! ?2 ✓!s 2 T big lrvsaT . Cd1 C-0 �1.N.fi�ai�di+s/Asscm6/y witiS f�'D /'dlro-/.305' =- --Ws.a • e4cre' '--,bores• - - � ,g11J' �1 , —TAo/'P/siy /�DO10' Attachment 17 •-e.Amco A,W ssewrd/y �vifif CEIr Va/ra 131/' NOTE- A//Tilbii79 is 2 r-'f'6'S'/Y-80 EUEBR RC�'2 wfs /r -e-e.+ SWANSON RIVER FIELD APPLICATION FOR INJECTION ORDER FOR GAS STORAGE WELL KENAI GAS STORAGE FACILITY #2 (KGSF #2) March 6, 2002 114 r1:R 1 1 20 f,1_ Alaska rail & Gas Cons. Commission Anchorage APPLICATION FOR INJECTION ORDER FOR GAS STORAGE WELL KGSF #2 TABLE OF CONTENTS Section/Regulatory Citation A. 20 AAC 25.402(c)(1) 20 AAC 25.252(c)(1) B. 20 AAC 25.402(c)(2) 20 AAC 25.252(c)(2) C. 20 AAC 25.402(c)(3) 20 AAC 25.252(c)(3) D. 20 AAC 25.402(c)(4) E. 20 AAC 25.402(c)(5) F. 20 AAC 25.402(c)(6) 20 AAC 25.252(c)(4) G. 20 AAC 25.402(c)(7) 20 AAC 25.252(c)(5) H. 20 AAC 25.402(c)(8) 20 AAC 25.252(c)(6) I. 20 AAC 25.402(c)(8) 20 AAC 25.252(c)(6) J. 20 AAC 25.402(c)(9) 20 AAC 25.252(c)(7) K. 20 AAC 25.402(c)(10) 20 AAC 25.252(c)(8) L. 20 AAC 25.402(c)(11) 20 AAC 25.252(c)(9) M. 20 AAC 25.402(c)(12) 20 AAC 25.252(c)(10) N. 20 AAC 25.402(c)(13) 20 AAC 25.252(c)(11) O. 20 AAC 25.402(c)(15) 20 AAC 25.252(c)(12) Subject Page Plat 1 Operators/Surface Owners Affidavit Description of Operation Pool Information Geologic Information Well Logs Mechanical Integrity Casing Information Injection Fluid Injection Pressure Fracture Information Formation Fluid Aquifer Exemption Wells Within Area 1 2 3 3 3 5 5 5 6 6 7 7 7 SWANSON RIVER FIELD APPLICATION FOR INJECTION ORDER FOR GAS STORAGE WELL KGSF #2 LIST OF ATTACHMENTS Number Description 1 Cook Inlet Location Map 2 KGSF #2 Location Map 3 Structure Map of Tyonek 62-5 Sand 4 SRU 212-27 Log Section 5 SRU 212-27 Production Data 6 Volumetric Gas Reserve Estimate 7 Material Balance P/Z Plot 8 KGSF #2 Wellbore Schematic (As planned) 9 Sample Gas Analysis 10 Leak Off Test for SCU 2438-4 11 Leak Off Test for SRU 223-28 12 SRU 12-27 Wellbore Schematic 13 Cement Job Reports for SRU 12-27 14 SRU 314-27 Wellbore Schematic 15 Abandonment Reports for SRU 314-27 16 Cement Job Report for 7-5/8" Casing in SRU 314-27 17 SRU 21-27 Wellbore Schematic SWANSON RIVER FIELD KENAI GAS STORAGE FACILITY APPLICATION FOR INJECTION ORDER WELL KENAI GAS STORAGE FACILITY #2 (KGSF #2) March 6, 2002 Introduction In 2001, Unocal commenced operation of a gas storage pilot project within the boundaries of the Swanson River oil field. Unocal refers to this gas storage operation as the Kenai Gas Storage Facility. In order to expand the capacity of the Kenai Gas Storage Facility, Union Oil Company of California (dba Unocal), as operator of the Swanson River Field (SRF), requests an injection order for injection of gas for gas storage purposes into a well to be called KGSF #2. Well KGSF #2 is planned as a redrill of SRU 212-27 with a 500' lateral in the Tyonek 62-5 sand. Section A - Plat Attachment 1 is a regional map showing the location of the Swanson River Field relative to other fields in the Cook Inlet area. Attachment 2 is a plat showing the location of the proposed injection well and the surrounding wells in sections 22, 27, and 28. Section B — Operators/Surface Owners The surface owners and operators within the area of this injection order and extending one -quarter mile beyond the boundary are: • Unocal • U.S. Department of the Interior, U.S. Fish & Wildlife Service i • Section C - Affidavit Affidavit of Gary A. Orr STATE OF ALASKA THIRD JUDICIAL DISTRICT I, Gary A. Orr, declare and affirm as follows: 1. i am over 19 years of age. I am employed by Unocal as an Advising Reservoir Engineer. I have personal knowledge of the matters set forth in this affidavit. r 2. On M A rL h l� , 2002, the surface owners/operators listed in section B were provided a copy of this permit application. j DATED at Anchorage, Alaska this b day of gftc ' , 2002. Gary A. Orr Subscribed and affirmed before me at Anchorage, Alaska on --414- Aw- e * Fa , 2002. Ata7 P °�1z3,2o�.".•�;�� Notary Public in and for the /e OF• P��, �� State of Alaska �llilllli►�,� My commission expires: to 2 Section D — Description of Operation Unocal proposes injecting gas into the depleted Tyonek 62-5 sand for gas storage purposes. The KGSF #2 well, a redrill of SRU 212-27, will be used for both injection and production. Well SRU 212-27 is the only well to have produced from this reservoir. SRU 212-27 will be redrilled with 500' of lateral into the 62-5 sand. The addition of the lateral is necessary to get the desired gas storage deliverability. The gas will be injected during the summer months and produced back in the winter months for sales. Section E — Pool Information The 62-5 sand of the Tyonek Formation is the proposed zone of injection. This depleted shallow gas reservoir is part of the Tyonek PA (8910086520-C). Gas from these reservoirs has typically been used on the lease for fuel. The Tyonek Participating Area (8910086520-C) is comprised of the stratigraphic interval the top of which correlates to the measured depths defined in the following wells: Top Tyonek P.A. Well Measured Depth SRU 212-10 5764 SRU 211-15 5640 SRU 234-15 5639 SRU 212-27 5322 SCU 341-4 5304 SCU 34-4 5123 SCU 21-16 5512 The base of the Tyonek Participating Area is equivalent to the top of the Hemlock Participating Area as defined in Unocal's October 2, 1995 letter to the AOGCC requesting expansion of the Hemlock Pool. The Hemlock Pool is defined in that letter in the following Soldotna Creek Unit wells: 41-4 (10,085'—10880' MD), 43-4 (10,168'-10,920' MD), and 41A-8 (10,116-10,880'). Section F — Geologic Information The Swanson River Field structure is a broad north -south trending anticline cut by a number of east -west trending normal faults. Oil and/or gas is produced from four formations at Swanson River Field. The shallowest gas production is from the Sterling Formation. The Sterling Formation extends to a depth of approximately 3500 feet and is comprised of thick sandstones, mudstones and coals deposited in a high-energy meandering to braided stream environment. Gas is also produced from the thinly bedded sands of the Beluga Formation that underlies the Sterling. These discontinuous sands were deposited in a lower energy stream system, and they are interlayered with abundant-mudstones and coals. The Beluga Formation is approximately 2000 feet thick at Swanson River Field. The Tyonek Formation is comprised of meander belt and braided stream sandstones interlayered with mudstones and thick coals. The Tyonek Formation is approximately 5000 feet thick at Swanson River Field, and gas is produced from several sands in the upper and middle part of the formation, while oil production comes from the lowermost 100 feet the Tyonek (the Tyonek G Zone). Underlying the Tyonek is the main oil producing interval at Swanson River Field, the Hemlock Formation. The Hemlock Formation is 600 feet thick at Swanson River Field and is comprised of thick conglomeratic sandstones interlayered with thin mudstones and minor coal. The 62-5 sand is a Tyonek sand that is present across most of Swanson River Field; however, it is only gas bearing in sections 27 and 28. The 62-5 sand gas column is penetrated by wells SRU 212-27, SRU 12-27, SRU 43-28, SRU 41-33 and SRU 34-28 as seen in the 62-5 sand structure map (Attachment 3). The attached log section for SRU 212-27 (Attachment 4) shows the 62-5 sand at depths from 6233 to 6253 feet measured depth (MD). Mudlog data indicates that the sand is fine to medium grained. The 62-5 sand is overlain by 13 feet of impermeable, claystone that is, in turn, overlain by 10 feet of coal, and 51 feet of water bearing sandstone. Underlying the 62-5 sand is 19 feet of impermeable siltstone and claystone that is, in turn, underlain by 21 feet of waterbearing sandstone. This waterbearing sandstone is underlain by over 230 feet of impermeable siltstone, claystone and coal. Porosity in the 62-5 sand, as calculated from the sonic log, ranges from 24% to 30%. These calculated porosities are affected by the presence of gas and are, in fact, somewhat lower. Applying the basic Archie equation with the following inputs: 1) sonic porosity, 2) m =1.6, 3) n = 1.8, and 4) Rw = 0.35 ohmm (10,000 ppm NaCI equiv.), results in Sw values averaging 47%. If the porosity is, in fact, 10% too high, then the true Sw would be 52%. The 62-5 perforations were added to SRU 212-27 well in September of 1997. The well was perforated from 6237 to 6254'. The peak gas rate occurred on 11- 28-97 at 4 MMCFPD. The well has produced a cumulative volume of 1.973 bcf from the 62-5 sand through January of 2001 (Attachment 5). Although the 65-7 was open from November 1996 to January 2001 its contribution is estimated to minimal as it was producing at low rates prior to the addition of the perforations in the 62-5 sand. 4 Initial volumetric estimates for the accumulation before the recompletion of SRU 212-27 were 3.04bcf (Attachment 6). The lower cumulative produced volumes indicate that this original volumetric estimate is inaccurately high. This inaccuracy is probably due to lower effective porosity values, and higher water saturations than originally expected. Material balance analysis of historical production and pressure data indicates an original gas in place of 2.9 bcf (Attachment 7). Using this figure for the original gas in place, the current recovery of 1.973 bcf corresponds to a 68% recovery. SRU 212-27 had produced all of its proven reserves from the 62-5 sand as of February 2001. The interval, which would not longer flow gas, was abandoned in February 2001 and the well recompleted into the 61-3 sand. The 61-3 sand has proven to be an uneconomical completion. Given the production history of the depleted Tyonek 62-5 sand, it should be a good gas storage reservoir. Section G — Well Logs All openhole logs from wells in the Swanson River Unit are sent to the Commission as the logs are completed. Attachment 3 shows a log section for the proposed injection interval in well SRU 212-27. Section H — Mechanical Integrity The KGSF #2 well will be tested for mechanical integrity using the standard 30 minute annulus test as per 20 AAC 25.412. To confirm continued mechanical integrity, Unocal will monitor daily the injection rates and pressures and notify the AOGCC the next working day if the rates and pressures indicate pressure communication or leakage in any casing, tubing, or.packer. The rate and pressure data will also be reported to the Commission on a monthly basis. Section I — Casing Information Attachment 8 is a wellbore schematic for the KGSF #2 well (proposed). The casing in SRU 212-27 was cemented in accordance with 20 ACC 25.252(b) and tested in accordance with 20 AAC 25.030(g) when completed. As evidenced in the attachment, the SRU 212-27 well is completed with 5.5 casing run and cemented down to a depth of 7800' MD and TVD. A DV collar was run in the casing string and is located at 4,430'. The bond log run 10/2/61 indicates a first stage cement top at 5800' and a second stage cement top at 2290'. The log indicates good cement bond in the proposed gas storage interval. Production data from this zone is supportive of a good cement bond. Section J — Infection Fluid The type of fluid for proposed injection is gas. The fluid composition for the proposed injection is dry natural gas with a specific gravity of 0.59. The properties of the gas are shown in the gas sample taken included as Attachment 9. Initially the source of the injection fluid is from the Hemlock formation within the Swanson River Field. Gas was injected into the Hemlock formation over the period of 1962 to 1992 for pressure maintenance purposes. This gas, termed "rental gas", is methane imported primarily from the Kenai gas field and the Trading Bay Unit. The produced gas today contains some heavier hydrocarbon components that are removed through various liquid extraction processes. The outlet gas from these processes would be used for injection into KGSF #2. In the future gas from other fields in the Cook Inlet will be injected and stored in Kenai Gas Storage Facility wells during the summer months and redelivered during the winter months. The estimated maximum amount of gas to be injected daily is 14 mmcfd. The injection gas should be fully compatible with the Tyonek 62-5 formation, since this zone previously contained dry methane gas and was produced without any signs of formation damage. Section K — Infection Pressure Existing compression will be used for gas injection and production operations. The estimated average injection pressure is 2700 psi. The maximum injection pressure will be 3000 psi. The compressor plant maximum output pressure limits the maximum injection pressure. Section L — Fracture Information The proposed maximum injection pressures for the gas storage operation will not initiate fractures in the confining strata which might enable the injection or formation fluid to enter freshwater strata. 0 The proposed maximum injection pressure for KGSF #2 in the 62-5 sand is 3000 psi tubing pressure (which is a..54 psi/ft gradient at the sand face). The injection pressure is limited by the compression capabilities at the Swanson River Field. Leak off tests in wells SCU 24313-4 and SRU 223-28, both new drills in the last five years, show the fracture gradient at approximately 2000' to range from .8 to 1.1 psi/ft (see attachment 10 and 11). Original reservoir pressure in the 62-5 sand in SRU 212-27 is estimated at 2716 psi based on initial shut-in tubing pressure measurements of 2400 psi. Using the reservoir true vertical depth of 6245', this equates to an original pressure gradient of 0.435 psi/ft. Section M — Formation Fluid No samples exist of produced water from the proposed injection interval. Section N — Aquifer Exemption The proposed gas injection will be at a depth of approximately 6233-6252' TVD. 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. Section O — Wells Within Area Well SRU 12-27 is within a quarter mile of the proposed KGSF #2. A wellbore _ schematic is shown in attachment 12. The 13-3/8" shoe tested with 1550 psi surface pressure (with 73.5 pcf mud in the hole puts the pressure test at 3051 psi at 2943' or 1.037 psi/ft) without breaking down. The 9-5/8" was set from 2736' to 7228'. The cement job of 500 sks of 116 pcf puts a theoretical top of cement at 5633', assuming 120% of calculated hole volume: The caliper log run two days prior to the cement job shows the hole to be close to gauge from 5820 to 7228'. The 9-5/8" X 13-3/8" liner lap did not initially test. The lap was squeezed and retested at 2000 psi surface pressure (with 91 pcf mud in the hole puts the pressure test at 3729 psi). The 9-5/8" liner was then perforated at 7208" and squeezed. The formation broke down under 2900 psi of surface pressure (with 91 pcf mud in the hole puts the breakdown pressure at 7454 psi or a fracture gradient of 1.03 psi/ft). The 5-1/2" production casing was run from 11492' to surface. The production casing was cemented in 2 stages. The second stage through a DV collar at 8178". A temperature log indicates a top of the second stage cement at 5410'. The portions of the drilling reports when the cement jobs occurred are attached as attachment 13. Well SRU 314-27 is within a quarter mile of the proposed KGSF #2. A wellbore schematic is shown in attachment 14. SRU 314-27 was abandoned in June 1992 (reports are attached as attachment 15). Cement plugs were installed at 404', 2,296', and 10,530'. The 7-5/8" casing string, which is located across the 62-5 sand (located at 6351' measured in this well), runs from surface to 10619' in 10-5/8" hole. The string was cemented in two stages. The first stage was 500 sacks of cement, pumped around the shoe. The second stage consisting of 1200 sacks was pumped through a DV collar at 8118'. Theoretical top of cement__ assuming 120% of calculated hole volume should be at 4302'. There are no caliper logs for this section of the well. A temperature log run right after the cement job was not able to get below 4920'. The log did not find a cement top. The drilling report for the cement job on the 7-5/8" casing is shown in attachment 16. Well SRU 21-27 is within a quarter mile of the proposed KGSF #2. Unocal's geologic interpretation is that the 62-5 sand in SRU 21-27 is not connected to the 62-5 sand that was depleted by SRU 12-27. A wellbore schematic of SRU 21-27 is shown in attachment 17. The 11-3/4" surface casing in SRU 21-27 was run from surface to 2029'. It was cemented with 1350 sacks of cement. Full circulation throughout the job and good returns. The 7" production casing was run from surface to 11,142'. It was cemented with 2,200 sacks with an average slurry weight of 116 pcf. The plug was not bumped. Cement was found in the casing at 9358' and cleaned out to 11000'. A cement bond log shows the top of good cement at 9000'. I I 1 I I I I .— ------- NII-01 1lu CAL I I I I 1 I 1 I I 1 I I I 1 I I I I COOK INLET ---- r--------- I --------- 7---- f 1 I I LOCATION MAP 1 1 1 1 BELU( I I I i i i RIVER -~ r- ---1 ; -------�-r-------� -,--------LT -- I I 1 1 I I 1 1 1 ;t- Aiii$Kii � I I I --1----1--------- L--------J-------Nc1U Ty - 1 1 LEVWS RIVER I 1 ----1------ - +------- —1— ----- ----------r------- I 1 1 1 1 I I 1 1 I 1 1 L I I 1 r I 1 PRETTY CREEK i 1 _I ® I 1 I LAKE i WAIN I I I 1 I RIVER 1 I I 1 1 I I I 1 I 1 1 1 I I I 1 t = 1 I 1 1 y,-- --1-------- J------------- - LI-------- T -�INCHOR�f�E r I I f I 1 I I I I I 1 1 1 I 1 I 1 1 1 t I I �� 1 1 I I ------ L—^-------I---------- --------- L-------- J---------- — I 1 PRANITE POINT 1 / 11 7! 1 NICOLA1 FACILITY f CREEK; I 1 1 I 1 I 1 I 1 1 SPARK 1 I 1 - I 1------J------ - SPURR ---�-- ; ; f 1 '� MONOPOD I ; 19N I KING SALMON I 1 , GRAYLING @9L'1__ _STEEL EAD __ BAK PRODUCTION �. 1 1 I FACILITY ; DOLLY VARDEN I 1 T!1 I I I C 1 I 1 I 1 j 77S ; PHIL"JPS LNG PLANT 1 1 1 NIKISKI I i i i FACILITY I I , 1 1 I I I I 1 17W I 16W DRIFT m• 15W ; RI4W ; R13W I RIVER -- 1 --- TERMIWAL ; 1 7- r--------1---------T------ ---t I , •, , CANtIGERY I I Tr 1 1 I I 1 I 1 1 I I COOINLET 1 1 I 1 1 1 1 1 I I 1 t 1 /GRAN BRUCE __ I�----------II---------�----------1-------+------------------1---------+— NAITE POI i i i i i i I f i I I 1 I---------1 I I------�— 1 I I t 1 I 1 I I I I I I I 1 1 1 1 1 I I I 1 I I I 1 1 I 1 I 1 1 ER--17--------Lr------ J1--------11r--------- IT --------- r----- 11--------- 4 I I I I I I 1 f 11 1 I 1 I I 1 1 1 I I I I 1 1 EAST FORELANDS I I I I t I 1 -- ----L--------I----------L--------- �------J---------L PROD. FACILITY------- �-- -- - t 1 I 1 SVVANSONIIRIVER • AGRIUM 1 1 FIEL© q CHEMICAL PLANT I 1 I I I t 11 1 • TESORO 1 BEAVER CREEK i 1 1 1 1 I -- --REFINERY ----1 ----1---------+----------+---------+---------�---------a-------=-+. I I I I 1 1 I 1 I I I I 0 1 5 10 I R12W I R11W 1 I 1 1 1 1 1 I RIOW , R91W I,CENA/ Sale in Miles ---------I I ----I 1 1 1 --I LOOPI r--------i- i---------�--------i---------�---------� ------ ' 'ACUMEXT 1 I I I I I 1 I 1 1 ------1 -----------JI --------1I --------L--------4--------1r-------- i---------I KENAI I I 1 1 R-!W L-IDmfifnglSwanson%COOKLOC.cdi SWANSO11q 23-22 S>1 RIVER I , 0 y '� 4 1 Mile 14-22 + UNIT SI Radius — 1 I , r (0 � 41-28 21-27 -�- / � Pro osed KGSF 2 1 � 9 Coml letion (0Q, I , I 12-27 212-27 , r�Op�� / 32-27 /27 43-28 5 — 1 23-27SI 1 1 314-27RD _28 31 —27RD-210 sI 314-27 Attachment 5 SRU 212-27 Production Report for the 62-5 Sand Completion Date Daily Gas Rate (MCFPD) Cumulative Gas Volume (MMCF) Daily Water Rate (BWPD) Cumulative Water Volume (MBBLS) Sep-97 571 17 0 0 Oct-97 2086 82 0 0 Nov-97 2819 166 0 0 Dec-97 3400 272 0 0 Jan-98 3104 368 0 0 Feb-98 2977 451 0 0 Mar-98 3190 550 0 0 Apr-98 3108 643 0 0 May-98 2836 731 0 0 Jun-98 2609 810 0 0 Jul-98 2817 897 0 0 Aug-98 2805 984 0 0 Sep-98 1775 1037 0.3 0.01 Oct-98 1490 1083 0 0.01 Nov-98 1504 1128 0 0.01 Dec-98 1787 1184 0 0.01 Jan-99 1552 1232 0 0.01 Feb-99 1724 1280 0 0.01 Mar-99 1192 1317 0 0.01 Apr-99 1421 1360 0 0.01 May-99 1475 1405 0 0.01 Jun-99 1130 1439 0 0.01 Jul-99 797 1464 0 0.01 Aug-99 1416 1508 0 0.01 Sep-99 1373 1549 0. 0.01 Oct-99 997 1580 0 0.01 Nov-99 1346 1620 0 0.01 Dec-99 1207 1658 0 0.01 Jan-00 1099 1692 0 0.01 Feb-00 1092 1724 0 0.01 Mar-00 964 1753 0 0.01 Apr-00 773 1777 1.33 0.05 May-00 1000 1808 .0.74 0.07 Jun-00 939 1836 0 0.07 Jul-00 669 1857 0 0.07 Aug-00 1074 1890 4.45 0.21 Sep-00 992 1920 6.17 0.39 Oct-00 790 1944 6.32 0.59 Nov-00 554 1961 0 0.59 Dec-00 332 1971 0 0.59 Jan-01 58 1973 0 0.59 Feb-01 0 1973 0 0.59 Mar-01 58 1975 0 0.59 Apr-01 43 1976 0 0.59 May-01 10 1976 0 0.59 Jun-01 0 1976 01 0.59 RESERVOIR DATA SHEET Field: Swanson River Well Name: 212.27 Reserves as of: 1l1/98 County: Operator: UNOCAL - State: Alaska Reservoir: 62-5C Fault Block: TEST DATA Date of test. SITP(pala): 0 Gas (mcfd): 0 FTP(psig): 0 Condensate (bcpd): 0 bc/mmcf: 0 Water (bwpd): 0 bw/mmcf: 0 RESERVOIR PARAMETERS Data Source Net Pay,ft.: 0 Porosity: 28.5% Sonic porosity Water Saturation: 44.2% hds Pressure Base: 14.65 Gas Gravity: 0.6 Estimate N2% 0.0°% CO2% 0.0% H2S% 0.0% Condensate(YIN) Y Pc: 670.98 Tc: 359.26 BHT,F: 117 WHT, F: 76 TVD(ft): 6078 Orginai BHP(psia): 2841.0 Pg = 0.465 Zi: 0.83309 Pressure Grad.(psi/ft): 0.486 OGIP, MCFIAF: 1453.2 Avg.Yield, BIMMCF: 0 Classification: PROVED PROBABLE POSSIBLE Status: Reservoir Area, Acres: 228 Net pay, ft.: 12.22 Reservoir Volume, AF. 2786.16 OGIP, MMCF: 4049 Fuel & shrinkage: Recovery Factor. 75% MMCF BBLS MMCF BBLS MMCF BBLS Ultimate Reserves 3,037 - - - - - Cumulative Production 272 Remaining Reserves 2,765 - - - - - Comments: 1) Mapped to gas/water in the 34-28 2) Apperant perm barrier saperating the 212-27 from the 314-27, 21-27 and 12-27, These wells all look wet In this sand. mjz Attachment 6 8/4/98 4000 3500 3000 WE 1500 1000 500 VI Attachment 7 SRU 212-27 -- Cum Production vs P/Z plot (Last updated on 7/29/00) y =-1179.2x + 3456.2 L RZ = 0.9776 --------------------------------------------------------------------------------------------------------- ------------------------------® ------------------------------------ -------------------------------------- / OGIP = 2.9 bcf 0.00 1.00 2.00 Cum Gas Produced, bcf 3.00 4.00 OAGas Cft\RScoit\POZ AII\212-27 Sam UNOCAL 76 Attachment 8 Swanson River Unit KGSF #2 Draft: Wellbore Schematic for Side -Track of SRU 212-27 Revised 3/6/02 RKB to TBG Head=14.32" CASING DETAIL SIZE WT GRADE TOP BOTTOM 22" 0' 32' 9-5/8" 40 J-55 0' 3455' 5-1/2" 17 N-80 0' 7800' (original hole) 1 3-1/2" 9.2 N-80 5800' 6300' 3-1/2" SSWWS 6300' 6800' L PIPE, and SCREEN DETAIL: L-80 0' 5800' PROPOSED JEWELRY DETAIL Item )' Methanol injection port (ID= 3.813") Gas Lift Mandrel 5-1/2" x 3 1/2" Liner hanger w/ PBR m milled in 5-1/2" casing at 5900' 3-1/2" WWSS Screen ----------------------------------- --------------------------------------- er cemented to liner top TD = ±6825' MD/5243'TVD KGSF #2 Draft Schematic.doc Drawn: 03/06/02 DRAWN BY: GAO ATTACHMENT 9 EG&G Chandler Engineering Modal 292 BTU Analyzer Test time: July3l 00 1.5:26 Calibration #: 1 Test #:4 Location No. :2340 Standard/Dry Analysis ..,_. Saturated/Wet Analysis Mole-s BTU* R.Den.* GPI!** Molelk BTU* R.Dea.* Methane 93.482 946.30 0.31.78 -- 91.855 929.91 0.5088 Ethane 1.880 33.34 0.0195 0.5028 1.847 32.76 0.0192 Propane 1.717 43.30 0.0261 0.4731 1.687 42.64 0.0257• i-Butane 0.327 10.67 0.0066 0.1071 0.322 10.48 0.0065 n-Butane 0.463 15.13 0.0093 0.1459 0.455 14.87 0.0091 i-Pentane 0.1.1.6 4.64 0.0029 0.0423 0.114 4.36 0.0028 n-Pentane 0.113. 4.46 0.0028 0.0402 0.109 4.38 0.0027 ( C6+ ) 0.171 8.69 0.0054 0.0737 0.1.68 8.54 0.0033 Moisture 0.000 0.00 0.0000 -- 1.740 0.88 0.0108 Nitrogen 1.566 0.00 0.0151 -- 1.539 0.00 0.0149 ( CO2 ) 0.1.68 0.00 0.0026 -- 0.165 0.00 0.0025 Total. 100.00 1.066.6 0.6081 1.3850 100.00 .1048.9 0.6083 * :-Uncorrected for -compressibility at GO -OF a 14.73OPS1A. **: L3raid:Volume reported at 60.OF. standard/Dry Analysis Saturated/Wet Analysis Molar Mass 17.612 17.619. Relative Density 0.6093 0.6096 Compressibility Factor 0.9976 0.9975 Ueating Value = 22928. Btu/lb 22539.,BtU/lb Heating Value = 1069.1 Btu/CF 1051.5 Btu/Cp Absolute Gas Density 46.6285 lbm/1000CF 46.6518'1bm/1000CF Wobbe Index = 1347.09 Unnormalized Total 92.895 Last Calibrated with Calgas of 1057.3'Btu/CP May 05 00 1.2:26 C6+ Last Update; GPA 2261-90. C6+ BVU/CF 5065.8, C6+ lbm/Gal 5.64250, and C6+ Mol.Wt. 92.00. 9 Report Well Name: SCU 24313-4 Attachment 10 Date: July 17,1999 Report #: 1s Platform: Swanson River Field: Swanson River Rig: Inlet Drilling C #1 Drlg Contractor: Inlet Drilling Project Objective: Drill & Complete Grass Roots Well AFE #: 134703 Spud Date: 7/12/99 Project: 9 days 15.0 hrs F/Spud: 5 days 2.0 hrs Current Hole Size: 6.000 inches Present Depth: 2,553 ft Drilling Hours: 5.50 hire Footage Drilled: 403.00 ft Average ROP: 73.0 ft/hr RKB Height (ft): 18.10 Last BOP Test: 7/16/99 Pressure (High), 5o00 Pressure (Low): 250 AFE Cost: $ 1,194,973 Daily Cost: $ 37,721 Previous Cum: $ 406,261 CUmulat(ve CSt' $ 443,982 ES Comments: None Days Without Accident: 50 Date: I Spills: 0 1 Spills to date: 0 1 AM Drill: PM Drill, 13017777— Ekafety MTGS.. Tourly meetings. Present Operation: Drill 6" Open hole Casing Shoo/Tubing information: Slow Pum Rates: p Size lb/ft MD TVD L071PPG Pump: 1 2 SPM 44 20 Press: 425 400 Liner: 5-1/2" 5-1/2" Strk: 9 14 De th 2,140 2140 Total POB: 19 76 DRLG: 2 Catering: Prod: Welders: Rig Cont: 15 Other: 2 Drilling 1: Nick Scales Foreman 2: Tim Brandenburg 13 3/8" 68 96 96 7" 29 2,150 2,150 15.7 Tool Pusher: Jerry Sandie . Boats: Helicopters: L-U-P From To HRS 0 eratlons Detail 0 00 3:30 3 30 " t=ounrfnew drawwor sic" brake pads to be wearPng unevenly on dril "rs»sTde. Remove two pads and Trim to allow tnefaceofdrum.`.__."` _ 5:00 5:30 fi:30 8:00 "_..........."......."..._ 10 30 " 00.. 14:00 15:b0 15:30 17:30" t300 "..4 30.'»»'»'"f 5:30 fi:30"»" 7M. " $.60 » 10:00 0 12rb0 14:00 15:00 15:30 17:30 18:00 19:30 »» AO 0:30 - » 1 0� "' T:00 " A:30" » 2:00 » 0:30 "Circulate _ "_ ..........._...» 1:30 " 2:00» f.00".. 0 $0 ' 2:00" 0:30»»' "»1:30'• Comp ete sli ng dr{i' R Ilne. Adjust breaks._."... RfH. Ta cement stun ers 1,997'.ltell u "�»''�"•''""'"»'"'"""""'""""" Break circulation. Clean out from 1,997' to boat collar 2,063 DPM. " Test P casing with ng pump. "Test to 1,000psT'fc� 15min. Ok. Test to 2,000psf,'15min. bk. '' " ""'"""""'""""'" Dr111 out loot collar at 2,Ofi3'. Clean out cement to 2 140'. W/ 0-8 , 30-35RPM, 228 M. 1,000psi. .' up cement. POOH standback 1"std�"»'»'"»»�"�'"•� ..._... _............_.. _..__.__.. RlJ and prep (o F'll drill pipe. Complete Mud pi cleaning and prep orr'change over. ............ "" "' """'""""""""'""""""` PU 3-1/2" 90 is dull 'i a In mouseliol'e"and stand"bacfl'i'n'de'rricli"� """ "" " """""""»'»"" """'"""" Circulate hole to new Mud, Dispose of used,mudd"own we11243-4MD. i2lJ"Dowell%r LOT.'F�ressure tes( lines fo 2500 psi,"t'esi casing to 2,000psi. with Dowell.»Ok » " "» "" "'"»�' Drlfl out shoe at 2,150 and'new Bole to 2,17d' WdI 2-4-K 96R M, 2 8gpm, 1,150ps1 G�'13U"tar leak ol# test. Perform LOl• uslng Doweil'pump unit�fransfer mud7irom rig to Dowell unit,'�est lines to 2b00'psl, Close Ciy3ril and""""""" pressure up on well . 150' 25 bpm rate, observe LOT with surface ressure 727psiwMWE 15 54Est L25 bbis " mud used to pressure up to LOT, bled back .25 bbEst »'Is mud one bbl mud ushed awto a rmation. Blow down Dowell pump unit, ear n[i"es, R/D Fa ne to pump true ''1'"al GTPR, l'er'1or �0 "drill l5r'ilf from 2, 70' to 2,55T WOB 2-41K, 5b RPM, P P P P P P P P' P 19 3'0 —Or' 4:30 MR SCU 2438.4 07.17.00.xls Page 1 of 2 Revised:7112100 by MWO Daily Operations Report ' ` Date: July 17, 1999 Well Name: SCU 24313-4 UNDCALO Report #: 15 Fluid Type MW TMP Visc PV yP Gels ES OM HTHP Cake Cl- orrecte 3 6 100 200 300 600 PPG f sec-1 tosdtomn (BHT) 32nd/]n I mud WP I Solids Fresh Water Gel] 9 72 50 11 23 11 15 0 97 1 200 3.5 9 11 23 30 341 45 Sample Loc.: Flow Line ITrip units Connect. Gas: units MAX. Gas: units Isack GRND Gas: units Btt# __3 Slze in MF Type Serial Number Depth (ft From To Dist Rotate Hrs ROP ft/hr Condition 1 0 D L B G O R 6 SEC/DBI FM2465 PDC 5996376 2,150 21553 403.0 1 5.5 73 BHA NO From To Length WT (kips) Flow (gpm) Press (psi) Description Hours on Jars: 10.0 3 1286.43 6" PDC 4-3/4" Mach 1/XL Motor with 5-7/8" Stab. _._,.,.._,.._._._._._____.,..,.._,...�,....._.»..._.._,.........,....._.»�_�_»_,.»»w..__ _._,...._.»... Sub 5 7/8", Stabilizer, with Float XO, with Totco Ring w,_.__.. _ _ _.. __.,.._._....... Monel DC XCI Mone] DC ___._...__..,.._....__._......._ _..._......_....._,........._..................__..._...................., ....................................._._....._..._.__....._..w..._._...__......._.........__..__...__.,... .._ _.._..,,.............._. tea. 4-3/4" Spiral DC »...-._..._......_........,........_. _..._ .._.._.. _.._.._..__. 4 3/4" Up Jar/Bumper Sub Combo 38 Jts. HWDP Weight -On -Bit Average: 3 Kips Maximum: 4 Kips Rotating: 3 Kips Sliding: Kips Drag Values: PU: 52.0 Kips SO: 42.0 Kips ROT: 45.0 = Kips Torque Values: On: 3400 ft-Ibs Off: ft-Ibs Max: ft-Ibs To Drive Information: Walk -About: Continued monitoring of43A-4 cellar and wellhead. No gas or tlui observed. Infection IocationM..-w_,_.µ_.....�.._....__...�..._....._._..._........__._..._..W._....�____.__............... �._.�.�..._._. ,......,. �........... MR SCU 2470.4 07.17.09.xls Page 2 of 2 RevisedIM2199 by MWO �- Attachment 11 CUM AFE# ACTUAL TIME AFE TIME ACCEPT RIG $513,122 126626 3.33 DAY 4.00 DAY 8/4/97 16:00 8/7/97- DRILL FROM 2074' TO CASING POINT AT 2125'. POOH, TIGHT HOLE FROM 1331'-600'. RIH WITH CLEAN OUT ASSY. REAM THROUGH BRIDGE AT 642'-685', WASH DOWN FROM 685' TO 750'. REAM TIGHT SPOTS AT 1425'-1455', 1600'-1640' AND 1877'-1925'. TAG BOTTOM AT 2125' WITH NO FILL. PUMP HI VIS SWEEP WITH NO SIGNIFICANT CUTTINGS RETURN. POOH WITH NO PROBLEMS. BEGIN RUNNING 7" SURFACE CASING. SWANSON RIVER #223-28 DAY 5-7 8/8-8/10/97 D.C. $63689 CUM $712145 AFE# 126626 ACTUAL TIME 6.33 DAY AFE TIME 7.00 DAY ACCEPT RIG 8/4/97 16:00 8/8/97--RAN 7" CASING TO 2125. CEMENT CASING WITH LEAD CEMENT OF 400 SX (140 BBLS) CLASS G WITH 4% BENTONITE, 2% CACL, AND .266% CELLOFLAKES AT 12.9 PPG, AND TAIL CEMENT OF 4 BBLS CLASS G WITH 2% CACL, .1 GAUSK D-145, .75 GAUSK D- 300. PROBLEMS PUMPING TAIL SLURRY DUE TO LOSING PRIME. DISPLACE CEMENT AND BUMP PLUG. FULL CIRCULATION THROUGHOUT JOB, CEMENT CONTAMINATED MUD TO SURFACE. ND DIVERTER AND RAN 1" TUBING TO 96', PUMPED TOP JOB WITH 74 SX CLASS G CEMENT. SET SLIPS, CUT CASING AND INSTALL TUBING SPOOL. NU ROPE. 8/9/97--PRESSURE TESTED BOPE TO 5000 PSI, WITNESSED BY LOU GRIMALDI-AOGCC. RIH WITH 6' BIT, TEST 7" CASING TO 3000 PSI. DRILL FLOAT EQUIPMENT. 8/10/97-DRILL 10' OF NEW FORMATION TO 2135'. PERFORM LEAK - OFF TEST WITH 9.0 PPG MUD AT 2058' TVD. BROKE FORMATION ' AT 1300 PSI = 21.1 PPG EMW. DRILL 6' HOLE TO 3923. SWANSON RIVER #223-28 DAY 1 (08/04/97) D.C. $160,171 CUM $394,968 AFE# 126626 ACTUAL TIME 0.33 DAY AFE TIME 0.33 DAY ACCEPT RIG 8/4/97 16:00 8/4/97- RU POOL ARCTIC RIG #123. ACCEPT RIG Q 16:OOHRS, 8/4/97. (FUNCTION TESTED DIVERTER 8/3/97). CLEAN OUT 13-3/8" CONDUCTOR WITH 12-1/4" BIT TO 86. PREP TO DRILL AHEAD WITH 8-1/2" BIT. DAY 2 8/5/97 D.C. $32,624 8/6/97 CUM $427,591 AFE# 126626 ACTUAL TIME 1.33 DAY AFE TIME 1.33 DAY ACCEPT RIG 8/4/97 16:00 8/5/97- DRILL WITH 8.5" BIT FROM 86' TO 158'. FLOW LINE PLUGGED WITH GRAVEL. CLEAN OUT AND MODIFY FLOWLINE. DRILL TO 162', KELLY HOSE FAILED, REPLACE SAME. DRILL FROM 162' TO 283'. LARGE AMOUNTS OF GRAVEL CAUSING HOLE PACK -OFF PROBLEMS AND FLOWLINE PLUGGING. f SWANSON RIVER #223-28 DAY 3 8/6/97 D.C. $46,886 8/6/97 CUM $474,477 AFE# 126626 ACTUAL TIME 2.33 DAY AFE TIME 3.00 DAY ACCEPT RIG 8/4/97 16:00 8/6/97- DRILL WITH 8.5" BIT FROM 283' TO 2074' (KICK-OFF POINT AT 500'). SWANSON RIVER #223-28 DAY 4 8/7/97 D.C. $32,006 8/7/97 I 1-70 Attachment 12 Y,..B.-TO TUBING HAI'IGER TUBMI , 11INGER ••, ! X-•MR PUP JT. (10.181 � 6 JTS. 2 a" EVE TBG. 19U .7 OT 7S BALL VALVE 5.21 r, t 53 JTS. '230 EUE 8rd TI3G.ud7.'4'1) CAM200 1.24 KUIDPXL 46 JTS, 2% It EUE 8rd TBG. . 13.Oc 1424.49 CAM20 XM YOWEL 13.15 ` ' 32 JTS. 0-11" ME 8rd TBG. • . 992-29 _ gMMO HA MIMED . 13.071, • . 20 JTS, 2 e" EUE 8rd TDG. 619.15 ._ CXMO HIM HIPJDREL . 13.01 • ' • • 15 JTS '•23" .EUE .837d 'TBG. .. GAI20 H4 RA11 REL ' 13.05 9 JTS. 2�8 SM 8rd TBGm . 281.39 -- CAM20 1.24 YANDREL 13.06 9 JTS. 2%r '.E,UE Bid 'TBG.' ' Ck= IM MPREL :.. 27$.47 ) �. 12.83 148.. JTS ..2;a". EUE •8rd .TBG. 4605.04 - OTIS "XA" 8MME 2 " ' • 2.46. .31.06 ._.. BROKI HS-16-1 HYD. PACER 28'" x .�" ' 3.9U :2 JTS. 2%1EUE 8rd TBG. Y ° -• .' 2 6,SO'. ,_. BROWN US-16-1- M. P�ACI:ER 245z. 5P ' . 3.94 -- OTIS "S" 1.50 Bgi r,R BLAST JT. ' 20.3'1 ►-- MOM "CC" 6,AvkTY X.P. , , • :.,.: 'W 'BArdR BLAST JT. 6.10 y... GTiS lowSLESYE 28" : ' 2.u6 }-• HIRMIi1 10-. 16-1 I -MD , 'PACKER 01P 3j'" 3.94 >- OTIS "S" NIPFIE,,. Position k'2.•• .., 1.50 - i3.iiiN.R BLAST M: & PUP .2;8 ' (20.31')(5.08 1) (15.00 ' )•(PUP 1:09 ') • 41.48 �,- OTIS "RA" SLEETS. 231a" . • : '• 2.88E -- STOP SUB , .50 }- STOP SGB & �?'. �L UIr'TTS x�SIllE IN:OD.' "F" TAG1wR 4•6`� CANCO "D" *FIPPLE (%Turnod down collar) . .93 72 FUP JT. 238' LIE TBG. CUT OFF GN 45". 12.12 Top of Tubing --- Top of Plug S R...0 CASING''.a.;;,T.U.131NG DETAIL, SECT.I.ON- .`27,•:c.SN,.,R.9.W. Top or Fbl Attachment 13 Mr. J. B. Hundley Drilling started: Drilling completed: Well completed: Total Depth: CO'LETION DATA (NEW WELL) SWANSON RIVER UNIT N0. 12- 7 - ALASKA. U.S.L. Anchorage July 4, 1959 Drilled by Mountain States Drilling Co. (Standard Oil Co. - operator) November 6, 1959 November 30, 1959 115001, plugged 314921-11396' and 10986'-10892' (bridge plug ®109E6t) Casing record: 20" conductor cemented at 30'. 13-3/8" 54.5# J-55 casing cemented at 2943t, stajje collar at 1019 t . ,,d; ? 9-518" 40# N-80 casing cemented at 72281, top at 273610 5-1/2" 23, 20, 17# N-80 casing cemented at 31492t, stage collar at 81781. Jet perforated with 4 1" holes per foot ln65'-111551, 108321-108101, 107902-10760t, 10750t-10726' and re -jet per- forated 10830'-10822' Junk: Sidetracked hole 34441-76221. Plugged 7279t-702011, 6755'-6590i', 6255t-6060+., 57781-5470:0., 36301-3344'. Following cemented and abandoned in sidetracked hole: Fish #1: 3642'-7601' consisting of 10-5/8" bit on 9 - 7-3/4" 0. D. D.C. 's on 3.17 jts. of 4— " drill pipe on stub '4" drill pipe. Per- 2fdrated 6. 2" S. H. P. F. 7279' 7280' ., 7274' - 7279, and 5 _2„ J.H. P. F. 7150' -7155 t . Per- forations 7279'-7155' squeezed with total 485 sacks cement. Perforated 5-a' J.H. P. F. 6755'-6750' and squeezed with 100 sacks cement. Perforated 5411, J. H. P. F. 6255' -6250' and squeezed with 05 sacks cement. Perforates 5-2" J.H. P. F. 5778' -5773' and sTieezed with 150 sacks cement. Perforated 5-2" J.H. P. F. 5254'-5249, 4885t-488ot, 4668t-4663', 466ot- '-4395' 4655' and (could not break dawn all perforations below 28*). Fish #2: 3515'-39031 consisting of 104 washover shoe on 387' x 7-5/8" washover pipe. COMpPIZT101F. yyMPO�RT Tl1i�v�) R �VrER Vi-1.:.T 12-27 Section 27, T. 8 11.1 R. ? W., eward 3S�: ' TA,' LRD OIL CO. OF CALIF-0 A OPERATOR Jul, 1959, cont'd. Cementing Detail Page 4. F'irot ":.age: ;Mixed 1000 sax Perma,nente construction type cement in 73 min to avera;;e 115 pcf slurry. Took 13 adn to insert tors � lug. Displaced cetl w/"5 bbl mud using rig ptap. pli.� in 33 mi.n 1500 pci. HOWCO cementing truck took over from ri,; pump as pl:.G bumped. Cen in place 3:49 AN. Used one top and one bottom rubber plug. 'econd "tab: Drop,.)ed DV opening; plug. Ports opened after 16 rain. Circulated ij •=in. 'Mixed 1000 sax Permanente const:n:etioa type cement in 79 rain to average 115 pcf olurry. Took 15 min to insert top plug. Displaced thru DV Parts ;. 1018' w/160 bbl crud using riG pump. BunVed plug in 13 min 1500 psi. HOWCO cemt'g truck took over from rig; puma as pluG burped. Cem in place := 11:11 AM. Used one top rubber plug. E'ull circulation throuChout cemt'S. Good cem returns on second otage. Evidence of channeling on first ata�Ze (jone clabbered cem to surface during, mixing of 2nd 3te.j'e cem follo-rjed by mud prior to wppeorance of aecond sta�,,e cem dt:ring second stale displacement). Casing Detail All '71 jts 2914.19 13-3/311, 54.57r, J-55, R-3, BR., >T=- , new, National Tube, J?-L, Ftewarts Lloyd,, etal. Cem.Equip. 5.33 HOWCO Guide Fhoe, Delter Differential fill -up collar one jt. up, baffle plate 2nd collar above shoe, HOV.'CO DV multiple stage cementer {7 1017-1G13' . 91�'" .52 Landed below X 2q.33 Cemented ; ' 2929�.4,0 10' cellar Casing is egi.1pped .;r/3 centrallizers: (1) 5' above shoe, (2) 5' below fill -up collar, (3) over 2nd collar, (") over 3rd collar, (5) over 4th collar, (6) over 5th collar, (7) 5' below DV collar and (3) 5' above DV collar. COMITION REPORT Page 5, �ANZON RIVET MM 12-27 "ection 27, T. doT. j R. 9 k'., e�vard MIN I''1'A:,'ilARD OIL CC. OF CALIFORNIA., UYE.-M.'Mi July 13-15, 195! ��ade up 13-3/8" casing head. Installed field welded spacer spool between csg. head and EOPE. Applied'162U psi to test 30PE. Held OK for 26 min, then lower 'lan.� i'. weld railed on spacer :pool. Rewelded f lan€;e and reinstalled BOFE. DUE tested at 1550 psi, for 50 tin - OK. .Ti:ly 16.,1959 Cleaned out to 101 below filluD collar. Tested BODE and caring 155O psi �!... for 3C min OK. Drilled 12- " hole 73-G pcf 3000, - 3387' 387' drilled Ju1,y 17-28, 195 Drilled 12" hole 75 pcf 3387' - 3459' 72' drilled Drilled 11-3/4" hole 70-73 pcf 3459' - 3915' 456' drilled Drilled 11" hole 70-76 pcf 3915' - 4015' 10CI drilled Drilled 10-5f3" hole 72-85 pcf 4015' - 7613' 35981 drilled J�AY 29, 1959 Drilled 10-5/8" hole ' 80 pcf 7613' - 7622' 9' da.-illed :tuck r 7601'. Encountered sudden increase in pit level, =d in hole started kickin,- at approx. 12:15 .14*1- Pulled off bottom 21' before pipe stuck. Cloced ZOPE in approx. 10 rein after start of mud activity. Bled off G.L th:u choke line from annulus in 30 edn while pugAng approx. 350 bbls 30 pcf mud thru DP. C0ITLETION REPORT PaC;e 13. Sk: MSON RIVER M= 12-27 .eat; on 27, T. 3 X- , R. 9 . , Seward 336uM ZA.;�.4 '.il UT.4 C 0 . 0.0 C 4 - viva`IA' UPi:;'A':'U { j ,ept ember ;0, cone' d. Cem 9-5G" x 13 3" laa @ a36' yJ200 sax. :`:potted 23 bbla water thru open ended DP 2737' • Pulled up to 2593' - UU ed 200 sa.% Pennanentc constrscLion tjj)e cem w/4s calcium e.ilcride added to avc;. 113-120 pef slue . EquaMzcd cem, pilled up to 2C161. Closed HOPE. Displ cem err/3L bbl =od. 'Iorl~.ice; prt:uc z•e 50L pai. Waited 25 :sin. sq.eezed ) I bbl mud b;; hesitation m. thad. Final vo .•kin press -,;re 2000 poi. Cem in -place 12:7$ P-H. :eun in bit,- located cem stz-ingero 2535. CO solet cem to 25831. October 1. 1259 CO soft ceM w/124't bit -to 26.20', hard cem 2620' -2736' . Pressure tested lap at 2„03 ;;:si =cox 30 min - Oak. Ran in w/w " bit. DO cem `2736' -2753' . DO --'!oat collar. Ran to shoe of +-5/3M?8 " c: ' . 1-To cem. Closed HOPE, p-ress%:':.'e tooted c.sG. W/ 1 JGG ,,si - cm. October 2, 1?59 Schltuaberter jet perf'd 5 - -I-" boles in 9-5/3" liner s' '72'V81. Squee:.ed Pere 72081 w/100 sa::. Sm- HOWCO retvie .*able cem retainer.__ 7151'. ro_:xLtiun .:4roke daim uncer 2;-OU psi. Preceded cem W/20 bbl. Water. Mi::ed 100 ra,:•. Pe_1=. t-ni:e constrv.ation tyLpe cem to nz) pc� Slurry. Di:p1 bbl vatcr Zcll.jwed by 95 bbl =Li(L Final worizin.- 2900 1,ci. Back scvttl,ed u4.)pro:.. 3 sa:t cem. st. 12 bbl cem t'� ru pew. In place 15 : i•i. 1 1> mi u m xina and pumi ing into place. October 3-4, 19S9 Drilled u " hole 7230 - 7590 October $, 1959 Drilled ed, 7-5%3„ hole 7500 - 7650 0ecobe_ �, 15 &-il l e:d l,0' drilled �l- 5 pC ;5 pcf Ran ;:chiumberser I-E^ 10C, 7227'-765c', rztcro-caliper lob; 7-?�1-7655', sonic loG 7422'7-7655' . CO.I'LETION RM)W SWAMN RIM UNIT 12-27 Section 27j. T. S N., R. 9 W.,-'ewa.rd BU-4 . STATHMAHD OIL CO.. OF CALIMUI:IA, OPEATOR September 23, 1959. Reamed and conditioned hole 625C-7230' . Ee*tember 2a, 1959 Cemented �-5ZW line_ 72120' w top " 2736'. Aft -or failure of leaf collar located 2 jts above s's:oe tahile running in hole, inLtalled Lecond _loaf collar top of joint io4, 05' below .'h ger. Used BaLms plain liner hanger grooved for cementing*'Wit4 2-; /4" holes belou slip :. man un. 4�" DP w%l jt c-7/0"tubing; stinger to Lxab cup ass . inside cce;. !lung 1 n: r 2 ft. off bottom C, 722.8' . Cemeutin& Detail Mixed 500 sa:: Pernanente coast-1Tction t;rpe cem to avg. llu' pc:e slarz-f in 45 min wZHOWC; cem ti' .C"ii. P---eceded cem w/20 bcl Sratcr. Dis:�I. cem v/ll- bcl water follaiied by 361•:- Vol )4 pc.L mud in 65 min. Tbeoretica.l distil, to 1WI above shoe W/no comp. allotra.nce. Full ret',ans t"-Zazut job. in place 1:50 41. Final worUng ygreos. 1000 poi. Liner Detail All 1J6 jts 4'434.97' 9-5/8", 40; x 11-00, R-3, SR, LTX, new, >pang Cerra Equip. ?a }7er 7. H014100 &aide shoe; ROVIC0 fL-;at collar . top of jt j `2, 7142' ; (YuC0 float collar top of jt ; 'iti4, 2651' . Bu a- plain liner hanjer 449P' Barger .. 2736, Bcttom Liner is equipped w/a centra,lliaerU on top of jtc 1, ', 4y 5, 6, 101, 1020 103, 105. yeptemte:^ 30, 1959 Pressure tested Took rsud 3 ',ra:s 1-71500 1-Doi. COMPIETION REPORT Page 21. SWANS011 RrM =T 12-27 section 27, T. 8 Id., R. 9 W., Seward B2.1-1 November 7, 1959 Ran Sehlumberger sonic log, 72231-1.1,424'; dip= -ter 7,2281-11,4241. Novembaer 8�1959 Circulated and conditioned. 'inning 5- " cs�;. November 9, 1959 Cemented 5-' ;' as . 11 492' in two stages. s . latt `:tom - Preceded cem w 30 bbls vrater. Mixed 600 sax Permanente construction ty,le cem w 0 .3% im-4 :.*tarder added in 30 min V/HDWCO seta truck., Displaced cem in 27 min using rig pump. Bumped plug w/2000 psi. In place 6:05 AM. 2ftage - Dropped DVopemtng bomb. Circ. thru DV collar8178 for hrs. Preceded cem z0 bbls water. :fixed 750 sax Perm. construction type cem *v '4- M-4 retarder added to avg. 118 pcf slurry w/itowco cem truck. Displ. cem w/rig pump in 18 min. Closed. DV ports w/3000 psi. Cem in place 8:15 AM. Cac•ing Detail Bottom 24 jts 1018.45 wext 1 jt 13.67 79 ,its 3334.14 90 jts 3082.12 TOP 95 jts 4o39.81 Cam. Equip, 7.14 Total 269 jts 1495.33 Abo•.re KB 3.52 Landed at ,.Ll 'd91.61 Cut 24 recami-ed 24.58 In hole 1 .. ,7.23 5','_'", 23k's I1-30, 11-32 3 R, L`.E'?•C, new, Younasto4m pup jt, AB AB 5x„� 17 , AB 7c , 20 ,, 'A cludes HOWCo Float shoe, Hof -co float collar on top of first . jt, HOWO self fillup collar on top of r.econd jt, HOWCO DV cementing collar 01731. .10' cellar Casing equipped 1-1/22 Halliburbon centrallizers: 2 on shoe joint, 1 on second jt, 1 on collar top of joints 3 thru 19 and on collar above and bezlo,,i DV collar. Iaer reciprocating scratchers at 10' intervals 10,700-10,370 and 11,110-11,240; also adjacent to centxnllize--c f- DV collar. Schlumberger temp. suinrey indicated top of second s-ta a ceia 5410' . Attachment 14 r Perforations 150'-155, ----- -_ PERFORATIONS 320'-324: 5.1/2" BRIDGE PLUG @ 404' DV @ 979' ragged TOC @ 2296' -1/2" RETAINER ® 2794' TUBING CUT r_I DV @ 8118' 5-1/2" HANGER @ 8797' 5-1/2" TIE BACK @ 8794' 7-5/8" @ 10,619' 2-3/8" RETAINER @ 11,030' PERFORATIONS 11,146-11,176' C, TUBING PERFORATIONS 11,185'-11 190' PERFORATIONS 11,184'-111246' PERFORATIONS 11,256'-11,290' 2-3/8" TUBING @ 11,282' SRU 314-27 IL Final 20" @ 30' JUNE 1992 Circulate 5-1/21IX7-5/8" Annulus 13-3/8" @ 2883' Note: All measurements are KB reference Original GL to KB is 15' 13.5 PPG MUD Perfs 7750'-7755' 8,945' KINLEY BUTTON (LEAKING) CALC TOC 10,530' 1 r; !ifi• 11,047 CAMCO M M MANDREL 11,103 BROWN PACKER 11,092' BROWN CC SAFETY JOINT 11,138 OTIS S NIPPLE 11,146' BROWN EXPANSION JOINT 11,156' CAMCO M M MANDREL 11,173' BROWN CC SAFETY JOINT 11,178' BROWN PACKER 11,212' OTIS S NIPPLE 11,225CAMCO M M MANDREL 11,242' CAMCO D NIPPLE CA-2 PLUG SET 6/3/88 11,246' BAKER PACKER FILL IN TUBING @ 11,260' 11,431' P BTD 5-1/2" LINER @ 11,436' 07/08/92 Attachment 15 ARCO ALASKA INC. DAILY OPERATIONS WELL: 314-27 -' BOROUGH: KENAI ACCEPT: 05/30/92 06:05 UNIT: SWANSON RIVER SPUD: FIELD: SWANSON RIVER RELEASE: 06/04/92 06:06 LEASE: OPERATION: API: 50-133-10154 DRLG RIG: NONE PERMIT: WO/C RIG: ROLLN RIG 5 APPROVAL: 05/21/92 ( 1) R/U ATLAS WIRELINE "@114341 MW: 0.0 TD: 0 RU SLICKLINE & PRESS TEST LURE. RIH W/ 1.85 GR. SCRAPED PB:11242 TBG F/ 10980 TO D NIPPLE AT 11222 WLM. RD SLICKLINE. BLOW DWN TBG PRESS FROM 1250 TO 0 PSI. FILL TBG W/ 70 BBLS FRESH H2O. PRESS TBG TO 400 PSI - 5.5 PC WENT TO 300 PSI. PC = 100 PSI. SC = 100 PSI. BLED TO 0 AND SD. 05/22/92 ( 2) "@11434' MW: 0.0 TD: 0 R/U ATLAS WIRELINE. RIH W/CCL & 1-11/16" HOLLOW CARRIER PB:11242 PERF CHARGE. PERF'D INTERVAL F/11185'-11,190' WITH 4 SPF. POH. RIH W/BAKER 2-3/8" CMT RETAINER. SET RETAINER @ 11, 176'. POH. R/D WIRELINE. 05/25/92 ( 3) "@11434' MW: 0.0 TD: 0 RU ARTIC RECOIL & HALIBURTON. PRESS TEST LINE TO 3000 PSI. PB:11242 RIH. HUNG UP ON CAMCO MM MANDREL @ 11047. STINGER FOR CMT RETAINER SLIDING INTO POCKET. POH. WAIT ON WIRELINE. RU WIRELINE. PRESS TEST LURE. RIH W/ 1.5" MCMURRY DUMMY & RA LATCH. FOUND POCKET @ 11036 BUT WOULD NOT SET. POH. RIH W/ L KICKOVER TOOL & 1.5" IMPRESSION BLOCK. SHOWED GLM POCKET TO BE EMPTY. RIH W/ L KICKOVER TOOL & 1.5" DUMMY W/ RA LATCH. SET DUMMY AND POH. RD. 05/26/92 ( 4) "@11434' MW: 0.0 TD: 0 RU ARCTIC RECOIL. PUMPED 10 BBLS H2O, CHECKED FOR FLUID TO PB:11176 SURFACE - WELL ON VACUUM. PT SURFACE LINES TO 3000 PSI.._ RIH W/ COILED TBG TO CMT RETAINER @ 11166 CTM. STABBED INTO RETAINER. PMP DOWN CT W/ 2000# SET ON RETAINER. ESTABLISHED INJ RATE OF .666 BBL/MIN @ 3000 PSI. MIXED 20 SX CLASS G CMT. PMP 4 BBLS.CMT + 10 BBLS H2O & STAB INTO RETAINER. PMP 12 BBLS H2O @ .5 BPM AND 2500 PSI PRESS INC. 2900 PSI W/ CMT @ PERFS. CIP 1245 HRS. UNSTING FROM RETAINER & FLUSH ANN W/ 43 BBLS H2O. GOT RETURNS. POH. RD. RU ATLAS WL. RIH W/ 2.365 TBG W/ 4 SPF F/ 11, 110-11115. POH. RIH W/ 2.365 CMT RETAINER & SET @ 11100. POH, RD. WELL 314-27 OPERATION: RIG : ROLLN RIG 5 PAGE: 2 05/27/92 ( 5) "@11434' MW: 0.0 TD: 0 RU ARCTIC RECOIL.PT SURF LINES TO 4000 PSI. RIH W/ COILED PB:11166 TBG TO CMT RETAINER @ 11086. ESTABLISH INJ RATE OF 1 BPM @ 3000 PSI. PUMP 5 BBLS CMT AND 10 BBLS H2O, STAB INTO RETAINER. PUMP 13 BBL H2O, 1 BPM. PRESS WENT TO 4000 PSI W/ CMT @ PERFS. FLUSH ANN W/ 48 BBL H2O. CMT RETURNS W/ 20 BBLS H2O. PRESS AT 7.625" ANN WENT TO 2500 PSI, PRESS AT 5.5 ANN WENT TO 2100 PSI. POH, RD. PRESS AT 5.5 ANN WENT TO 250 PSI. RU ATLAS WIRELINE. RIH W/ 1 11/16" PERF GUN. PERF TBG F/11068 TO 11073. TAG CMT @ 11083. POH. RIH W/ 2.325 CMT RETAINER TO 11030. POH, RD. BLED 7.625 ANN TO 500 PSI, 5.5 ANN TO 0 PSI. 05/28/92 ( 6) "@11434' MW: 0.0 TD: 0 RU ARCTIC RECOIL AND HOWCO. RIH W/ COILED TBG TO CMT PB:11009 RETAINER @ 11009 CTM. STAB RETAINER. ESTABLISH CIRC RATE OF 1,BPM @ 3500 PSI IN 5.5 ANN. CIRC 20 BBL H2O @ 1.5 BPM AND 4800 PSI. RETURNS CUT W/ CRUDE. PMP 11 BBL CMT + 17 BBL H2O @ 1 BPM AND 3200 PSI. POH W/ CTU TO 10300. CIP 10:35. FLUSH W/ 37 BBL H2O. FULL RETURNS. POH, RD. PRESS REDUCED TO 0 BUT SC TO 250 PSI. 05/29/92 ( 7) "@11434' MW: 0.0 TD: 0 RU ATLAS WIRELINE. RIH W/ 1 11/16 PERF GUNS. TAG CMT PB: 7780 STRINGERS @ 7730 TO 7780+(CALC TOC @ 10,5301). JOE DYGAS APPROVED ORIGINAL WELL PLAN MODIFICATION. POH. RIH W/ NEW 1 11/16 PERF GUNSS. PERF 2.375 TBG W/ 4SPF FROM 7750-7755 CIRC 13.,5 PPG MUD TO SURFACE. POH. R/D. SET PRESS VALVE, SEC WELL. 05/30/92 ( 8) ACCEPTING RIG/ NU BOP "@11434' MW: 0.0 TD: 0 ACCEPT AND R/U ROLL'N 5. PB: 7780 05/31/92 ( r9) REPAIR MUD PUMP "@11434' MW: 0.0 TD: 0 R/U WATER LINE TO MIX MUD. N/D TREE. N/U EXTENSION SPOOL PB: 7780 AND MUD CROSS. N/U PIPE RAMS 2.375" AND ANNULAR PREVENTER. N/U KILL LINE AND CHOKE. PULL BPV AND SET CV. TEST BOP, MUD PUMP LEAKING.' REPAIR MUD PUMP. 06/01/92 ( 10) TEST BOP 11011434' MW: 0.0 TD: 0 TEST BOP, RAMS, LINES, HYDRILL, CHOKE MANIFOLD, MUD PB: 7780 MANIFOLD. MIX MUD T0.13.5 PPG. R/U ATLAS WIRELINE. RIH AND CUT 2 7/8" TBG @ 3072. POOH, L/D 98 JTS 2 3/8" TBG. NO CORROSION. CHANGE TO 2 7/8 RAMS. TEST PIPE RAM DOOR TO 1000 PSI. M/U BRIDGE PLUG, TIH. CONINUE TIH W/2-7/8" DP. SET 5-1/2" HALLIBURTON EZDRILL BP @ 2987. PRESS TEST 5-1/2" CSG TO 1500 PSI(TEST GOOD) POOH W/2-7/8" DP. WELL 314-27 OPERATION RIG : ROLLN RIG 5 PAGE: 3 06/02/92 ( 11) WOC/COND MUD "@11434' MW: 0.0 TD: 0 POOH W/ 2 7/8 DP. L/D 6 JTS. MIX MUD TO 13.5 PPG. R/U PB: 2350 ATLAS WL. RIH W/ PERF GUN. PERF 5.5 AND 7.625 CSG W/ 4 SPF F/ 2850-2854. POOH. R/D WL. ESTABLISH INJ RATE OF 2 BPM @ 800 PSI. MU 5.5 HALIBURTON BRIDGE PLUG. TIH. SET PLUG AT 27941. R/U HALIBURTON AND PUMP CMT. PUMP CMT JOB AS FOLLOWS: 5 BBL WATER, 300 SX CLASS G CMT W/.15% HALAD 344 + .2% CFR3 + 1% CALL, 61 BBL SLURRY MIXED @ 15.8 PPG. SPOT 50 SX(10BBL)CMT ON TOP OF CMT RETAINER. EST TOC @ 2350'. POOH. WOC-MUD CMT CONTAMINATED INSIDE DP. REVERSE CIRC & COND MUD @ 2000'. CONTINUE POOH AFTER COND MUD. 06/03/92 { 12) "@11434' MW: 0.0 TD: 0 CIRC AND COND MUD. P/U BIT AND BIT SUB. RIH W 2.875 DP. TAG PB: 0 CMT @ 2296' W/ 5000#. POH. L/D 6 JTS DP. PMP DRY JOB. POH. L/D 2.875 DP. P/U HOWCO BRIDGE PLUG. RIH AND SET AT 404'. POH AND L/D DP. R/U ATLAS WL. RIH, PERF F/320-324' W/ 4 SPF. POH. ATTEMPT TO CIRC DOWN 5-1/2" LINER. PRESS UP TO 2000 PSI. UNABLE TO CIRC UP 7.625`CSG. R/U ATLAS WL. RIH, PERF F/ 150-155 W/ 4 SPF. POH. EST CIRC THRU PERFS 2 BPM, 200 PSI. PMP CMT. MIXED & PUMPED 7 BBLS CLASS G CMT + CFR3 + HALAD 344 + CACL @ 15.8 PPG. HAD GOOD CMT RETURNS TO SURFACE. CIP 18:30 HRS. DRAIN AND WASH BOPS. N/D BOP AND L/D DERRICK WHILE MIX MUD FOR SRU 21-15 P+A. 06/04/92 ( 13) RIG RELEASE "@11434' MW: 0.0 TD: 0 MIX 415 BBL 13.0 PPG MUD FOR SRU 21-15 P+A. CLEAN MUD PITS. PB: 0 RELEASE RIG. 06/13/92 ( 14) "@11434' MW: 0.0 TD: 0 DIG OUT CELLARS ON BOTH WELLS W/BACKHOE.HAUL CMT CELLAR PB: 0 WALLS TO KENAI BOROUGH LAND FILL. HAUL OIL CONTAMINATED SOIL TO SWANSON RIVER SOLID WASTE DISPOSAL PTI. WELD P & A MARKER POST & BACK FILL HOLE W/GRAVEL. SIGNATURE: ,a, 1g, 1. DATE: _% 1 Z9 J &Z (drilling perintend ) Attachment 16 DAILY PROGRESS OF DRILLING WELLS Pr®-562 Drilling Days. CONTRACTOR WELL NO` �7 c� 7 OR UNIT 1 � . .DEPTH 1T NO SIZE MAKE AND TYPE t FROM FT, TO FT_ FT, IN NRS TONS WT. ON BIT SPEED DRILL COLLARS J CASING FORMATION ' SIZE DRI.G. FLUID_ sEC CC IPd /, TTPE WEl6HT # VISCOSITY WATER LOSS FILTER CAKE SAND SALT ROLE`S12ES. SURV�! b eA � O j L; 5 it C top 16 joints 605 ft. P 110 LT&C 29.7# 8 rol$. thread.. Next 152 joints 6170 ft. N 80 2Q,'7 TTRr A rrn�nr� th join Total casing length 10651 includes DV collar and float equipment. Landed casing at -1062G belr�,r-; ---owing-e u pped-:.witth--Gees"Gries-a•s fe11ows=ghee-_4-4 —4- 4 Halliburton flow shoe, Halliburton self fill differential collar at top of shoe joint. centralizers placed on each of bottom 25 joints. CEMENTING -.DETAIL: First Stage: oncfftion`mud or ours. umpe s wa er ea xe sac s cons ruc on cement with , 3� HR-4 retarder in 40 'minutes. Dis laced cement 'c ith rig pump in 49 min. • ;a;•.•::f':;;.,;t.eil plug final pressure -1-800 p.s.i• . Dis lac pressure 1000 p.s,i. Second —Stage. .`, •:. , .' Dro Mt4 DV opening bomb. DV collar opened after 58 •In Circulated and conditioned :. mud through DV collar at 8118. Pumped 30 bbls. of water ahead. Mixed 1200 sacks pump 4AL� Closed DV collar with 2100 p.s.i. Second Stage Cement in place @ 3:57 PM. Use ' 'tH en-egtrx . weight Landed casing in the -as cemented position. MORNING TOUR-- Ran Schlumberger temperature survey. Survey would not go below 4920, a _ FOREMAN •... ,. � ~.��.sw.: wn^.tag... .. �._. .'.. ...... :. ... ... ..... �. ,, .. .. ....� ....... .. DAILY PROGRESS OF DRILLING WELLS Pro-562 -7C DrI ing Days_ 1NE11 NO I ti Z ORUNITAAI_� �S-f-A- i_C:�", "1' -- Lam} ]9 DEPTH b l � BIT NO 1 2-- ( _ -l�f t4 tt �. d Ln1 SIZE MAKE AND TYPE FRO FT. TO ff FT. IN HRS TONS MIT. ON BIT SPEED DRILL COLLARS CASINfl l A, b c^7- b FORMATION I SCC IN �o ORLG. FL1iID TYPE WEIGHT —# EC VISCOSITY WATER LOSS FILTER CAKE SAND SALT HOLE SIZE t DETAIL: a � u (� v C_ C c.. t_ (,\-tom ► I. wo WT.) c c fc.-e f� MORNING TOUR. ' Q !!r t pl_vc,�.� FOREMAN . a /r: 41 G/ �, - .. `�: j , :. _, _ _. ,• ^ �ASlNG � Tu6lNG D�'iA/L ____. d"`'T, �• L per /2-.�/ - 6,z _.. •• /01 _. ed ti Ll 11 bro_ "��• �~ '• PPP✓�'s:2%'Tb,irq-R85' • � ��C�e v��Lp�,,plE-�G ^� t M4+teS' • Co+mao iilMiYlo�7die/Assemb/y wiih RO !/c>/ram ^/2.A9' ,�E,� � .. cm24 et Il?.a 2029' -- t9 2/ 4b • Comoo.HW*l vx•vi e•i/ Xss mh10 wi/h AV , 4W v -12o,f � e� • ¢/✓/s 2%'Tb6,;v-/293.89' .;, •' m - • �_� C.�mcb.tl.H,f/an�o�ir/ .9ss�,n.6/y wifii'iS'D X�%r��--/3302' �e•� Grrc �!"1 � rT ca1nco .b1t1.N airo'rr / �sicm•6�y ,r,Jh f�v 6�r/vd- -/-FOS'+-S`� 7 -I G`t',�?.99' Campo iF1Al�'ana'>P/ Ass..-vnb/y c'ses• 26 ✓ts, 2Y "rabi�g-B2J. SD' � -{- • _._. rdsr, 48• • Camce rFlit9,69andre/ r4ssrm.6/y s.�:rh �'D lid/rr -1.�00 ; 5 -C t �� O /gfe�.rr•--. --.as•�s•• . . 1f�L.1G13� + ! a . �T'V A?PA • �� _ •--,�g6os• -.�v orfVug /IoO�O' rd ll/92' Attachment 17 ,nc o ,tv'.,�i'.f/vndr�/ .�sumd/y �i,55 R'o -/a?OS' .. rtt of r} ^-erica ,ff,¢f itlano�i-6►/.•lsse�L/y wii'ry Cfli l��•/re-%t // ` -/d/.' P�'l Miry -.�'/. S/' e . •• • � � . drown CC' Sa/el dl. -/.06'' • • —Ye��`uri Shoe-.•�3' ' ' o.. wrs s•s-cf