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Home My WebLink AboutCO 370Index Conservation Order 370 Granite Pointe #53 & #54 1. January 12, 1995 UNOCAL Requests for Spacing Exception 2. January 18, 1996 Notice of Public Hearing, Affidavit of Public Hearing 3. February 20, 2020 BPXA's request for Amin Approval for Conforming PBU Greater Pt. McIntyre Area Satellite Pool Rules for Consistency (CO 370.010) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re~ TIlE APPLICATION OF UNION OIL COMPANY OF CALII*ORNIA for an order granting an exception to spacing requirements of Title 20 AAC 25.055 to provide for the drilling of the Granite Point No. 53 development oil well. ) Conservation Order No. 370 ) ) Union Oil Company of Califomia ) ) Granite Point No. 53 ) ) February 16, 1996 IT APPEARING THAT: Union Oil Company of California (Unocal) submitted an application dated January 12, 1996 requesting exception to 20 AAC 25.055(a)(3) to allow drilling the Granite Point State No. 53 development oil well to a producing location that is closer than 500 feet to a drilling unit boundary. 2. Notice of opportunity for public hearing was published in the Anchorage Daily News on January 19, 1996 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FIND~GS: The Unocal Granite Point State No. 53 well as proposed will be a deviated hole drilled from a surface location 2855' from the south line and 3991' from the east line of Section 13, T10N, R12W, Seward Meridian (SM) to a bottom-hole location 1177' from the north line and 408' from the west line of Section 25, T10N, R12W SM. 2 Offset, owner Mobil Oil Company has been duly notified. 3. An exception to 20 AAC 25.055(a)(3) is necessary to allow drilling of this well. CONCLUSION: Granting a spacing exception to allow drilling of the Unocal Granite Point No. 53 well as proposed will not result in waste nor jeopardize correlative rights. Conservation Order N~ ~ February 16, 1996 Page 2 ? NOW, Tlt-EREFORE, IT IS ORDERED: Unocal's application for exception to 20 AAC 25.055 for the purpose of drilling the Granite Point No. 53 well is approved as proposed. DONE at Anchorage, Alaska and dated February 16, 1996. Alaska Oil ~ation Commission f!?. ucluckerman. A. Babcock, Commissioner Alaska Off and Gas Conservation Commission AS 31.05.080 provides that within 20 days atter receipt ofw~itten 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 ff 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 1 O-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 hms from the date on which the request is deemed denied (i.e., 10th day atter the application for rehearing was filed). THE STATE °ALASKA GOVERNOR MICHAEL J. DUNLEAVY Ms. Katrina Gamer Alaska Oil and Gas Conservation Commission ADMINISTRATIVE APPROVAL CONSERVATION ORDER NO. 207D.001 CONSERVATION ORDER NO. 311B.003 CONSERVATION ORDER NO. 317B.003 CONSERVATION ORDER NO. 329B.005 CONSERVATION ORDER NO. 345.002 CONSERVATION ORDER NO. 362A.006 CONSERVATION ORDER NO. 570.010 PBU Area Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: CO -20-003 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.ocgcc,olasko.gov Request for Administrative Approval for Conforming Prudhoe Bay Unit (PBU) Greater Point McIntyre Area Satellite Pool Rules for Consistency Prudhoe Bay Unit Lisburne Oil Pool — Conservation Order (CO) 207D West Beach Oil Pool — CO 311 B Pt. McIntyre and Stump Island Oil Pools — CO 317B Niakuk Oil Pool — CO 329B North Prudhoe Bay Oil Pool — CO 345 Greater Point McIntyre Area — CO 362A Raven Oil Pool — CO 570 Dear Ms. Garner: By letter dated February 20, 2020, BP Exploration (Alaska) Inc. (BPXA) requested administrative approval to amend the pool rules in the above referenced orders to bring conformity and consistency to the rules governing operations in the pools in the Greater Point McIntyre Area (GPMA), to make operations more efficient, and to make compliance oversight for the Alaska Oil and Gas Conservation Commission (AOGCC) simpler. There are several requests that apply broadly across multiple GPMA pools. These are as follows. COs 207D.001, 31113.003, 31713.003, 32913.005, 345.002, 362A.006,570.010 April 3, 2020 Page 2 of 12 Well Spacing Requirements: Currently, the Lisburne Oil Pool (LOP) has an interwell spacing requirement of one well per government quarter section and no pay opened within 1,000 feet of another well. The West Beach Oil Pool (WBOP) has an interwell spacing requirement of one well per 160 acres until circumstances warrant the AOGCC changing it. The Pt. McIntyre Oil Pool (PMOP) has a spacing requirement of one well per 40 acres with no pay open within 500 feet of another well. The Niakuk Oil Pool (NOP) gives the AOGCC the authority to approve the drilling of any well that is at least 500 feet from the affected area boundary and does not have open pay within 1,000 feet of another well. The Raven Oil Pool (ROP) has an interwell spacing requirement of 20 acres with no pay open within 500 feet of the affected area external boundary. BPXA requests that the interwell spacing requirements be eliminated and that the only spacing requirement be a 500 -foot offset from property lines where the landowner is not the same on both sides of the line. At the time the spacing requirements in these pool rules were imposed wells were being drilled nearly vertically. Because modern horizontal and multi -lateral wells are now being utilized to develop pools, BPXA needs flexibility to drill wells as dictated by the geology and reservoir models in order to maximize recovery. Standardizing the spacing requirements by eliminating interwell spacing requirements while retaining property offset requirements will result in improved recovery while protecting correlative rights. Pressure Survey Requirements: BPXA requests that the pressure survey requirements be modified so that compliance with regulatory oversight becomes simpler and data is collected in a meaningful manner. Currently, the Lisburne Oil Pool (LOP) requires at least one pressure survey be taken each year from each producing drillsite and that the results be submitted monthly, while the West Beach Oil Pool (WBOP), Pt. McIntyre Oil Pool (PMOP), and Niakuk Oil Pool (NOP) require one pressure survey per producing governmental section per year and results submitted quarterly. North Prudhoe Bay Oil Pool (NPBOP) requires one pressure survey per producing governmental section but doesn't specify when the results need to be reported, and Raven Oil Pool (ROP) requires one pressure survey per reservoir compartment where production wells exist and specifies the results are to be reported in the annual reservoir surveillance report. The inconsistency in where pressure surveys need to be collected and how the results are to be reported makes it more difficult for the operator to stay in compliance without yielding any benefit that could not be obtained by more uniform collection and reporting requirements. Moreover, after decades of development and reporting, the pools in the PBU are well understood and have sophisticated reservoir models. At this point, monitoring of reservoir pressure is important for proper reservoir development and targeted pressure surveys would provide the most useful information for reservoir development purposes. Presenting the results of the reservoir pressure surveys from the prior year in the annual reservoir surveillance report and proposing a plan for collection of reservoir pressure surveys in the coming year as part of the annual reservoir surveillance report will give the AOGCC an opportunity to review the data and ensure the proposed plans are adequate. This is consistent with how the other pools in the PBU are managed. COs 207D.001, 311B.003, 317B.003, 329B.005, 345.002, 362A.006, 570.010 April 3, 2020 Page 3 of 12 Well Testing: The GPMA pools have inconsistent well testing requirements that include quarterly allocation process reviews, monthly allocation reports, determining water volumes by API approved methods or an on-line water cut meter, monthly or annual API gravities for each well depending on the pool, gas samples collected yearly from each non -gas lifted producer, a minimum of two well tests per well, and twice monthly well tests. BPXA requests to eliminate the quarterly allocation process reviews and monthly allocation reports and proposes instead to provide an allocation factor report as part of the annual surveillance report as is done elsewhere in the PBU. BPXA also requests eliminating the water volume calculation, API gravity, and gas sampling requirements since at this point, recovery methods in these pools are unchanging and render this data of little benefit. Finally, BPXA requests to eliminate the requirement to test each producing well at least twice each month and instead require a minimum of one test per month per well. This request is consistent with how the rest of the PBU is managed and allows BPXA to maximize its well testing resources by testing the wells with stable production less frequently and testing the wells with less stable production more frequently to improve the overall allocation of production. Additionally, BPXA makes several requests that apply only to a single pool. These include the following. LOP Gas Oil Ratio (GOR) Testing Requirement: The LOP requires a GOR test on each producer within 90 to 120 days of commencement of regular production and then semiannually thereafter. The monthly well testing requirements for allocation purposes will provide adequate information as to the producing GOR of the wells so as to render the current rule unnecessary. LOP Gas Cap Water Injection (GCWI) Project: BPXA proposes to remove the 20,000 BWPD injection rate limit and raise the injection pressure limit from 0.55 psi/ft to 0.85 psi/ft. When the LOP GCWI was initially approved it was thought that the water injection rate and pressure must be constrained to prevent parting the LOP matrix to prevent premature water breakthrough. After several years of operation, such strict limits on injection rates and pressure do not appear to be necessary and the GCWI project will still function as planned if injection rates are constrained to 0.85 psi/ft. PMOP Enhanced Oil Recovery (EOR) Project Report: BPXA requests elimination of the annual EOR project report for the PMOP because miscible injectant for this pool is now being supplied by PBU Central Gas Facility and not from the Lisburne Production Center. As such, a PMOP EOR project specific report is no longer needed as the MI composition is the same as elsewhere in the PBU. Conclusions: Each of the affected COs contain an administrative action rule that allows the AOGCC to administratively amend the orders provided the proposed change does not promote waste, jeopardize correlative rights, is based on sound engineering and geoscience principles, and will COs 207D.001, 31113.003, 317B.003,329B.005,345.002,362A.006,570.010 April 3, 2020 Page 4 of 12 not increase the risk of fluid movement into freshwater. All of BPXA's requested changes comply with these requirements. The proposals to consolidate the rules across the GPMA pools, eliminate or modify the GOR testing and GCWI project rules in the LOP, and eliminating the requirement for an unnecessary EOR project report for the PMOP will simplify operations for BPXA, make uniform the compliance requirements, and will not impact ultimate recovery. Eliminating interwell spacing requirements, while maintaining a minimum offset distance from property lines where ownership changes, will maximize ultimate recovery while also protecting correlative rights. The only proposed change that could potentially have an impact on fluid movement into fresh water is the elimination of the water injection rate limitation and increasing the water injection pressure limitation for the LOP GCWI. However, since the proposed injection pressure limit is below the fracture gradient of the confining interval this will ensure the LOP GCWI injection remains in the LOP. The proposed changes can be made administratively. Finally, on its own motion, the AOGCC is revising the administrative action rules, where necessary, to be consistent and uniform with the language currently used by the AOGCC for these rules. Now, therefore, it is ordered that the subject conservation orders are amended as shown below. Lisburne Oil Pool — Conservation Order No. 207D Rule 3. WELL SPACING There shall be no restrictions to well spacing within the affected area except that no pay may be opened in a well which is closer than 500 feet of an external property line where the owners and landowners are not the same on both sides of the line. Rule 9. GAS -OIL RATIO TESTS (Rescinded) Rule 10. PRESSURE SURVEYS a. An Annual Pressure Surveillance Plan shall be submitted to the AOGCC in conjunction with the Annual Lisburne Oil Pool Reservoir Surveillance Report by June 15n' of each year. This plan will contain the number and approximate location of pressure surveys anticipated for the next calendar year and, unless AOGCC orders otherwise, the plan will be deemed approved 45 days after submission to AOGCC. b. Data from the surveys required in (a) of this rule shall be submitted with the Annual Lisburne Oil Pool Reservoir Surveillance Report by June 151 of each year on Form 10- 412. Data submitted shall include rate, pressure, time depths, temperature and any well condition necessary for the complete analysis of each survey. The datum for the pressure surveys is 8,900 true vertical feet subsea. Transient pressure surveys obtained by a shut-in build-up test, and injection well pressure fall-off test, a multirate test, or an interference test are acceptable. Calculation of bottom -hole pressures from surface data will be permitted for water injection wells. Other quantitative methods may be administratively approved by the AOGCC. c. Results and data from any special reservoir pressure monitoring techniques, tests, or surveys shall also be submitted as prescribed in (b) of this rule. COs 207D.001, 31113.003, 317B.003,329B.005, 345.002, 362A.006, 570.010 April 3, 2020 Page 5 of 12 Rule 16. GAS -CAP WATER INJECTION PROJECT a. Water injection is authorized into Well L5-29 only and is limited to perforations within the upper Wahoo Formation (Zone 6) between the measured depths of 13,585' and 13,634'; and b. Injection pressures must be maintained below 0.85 psi/ft. West Beach Oil Pool— Conservation Order No. 311B Rule 3 Well Suacina There shall be no restrictions to well spacing within the affected area except that no pay may be opened in a well which is closer than 500 feet of an external property line where the owners and landowners are not the same on both sides of the line. Rule 7 Common Facilities and Surface Commingling a. Production from the West Beach Pool may be commingled on the surface with production from other pools prior to custody transfer. b. NGLs will be allocated to each pool based on actual gas production volumes and NGL process simulations. Process simulations will be updated at least once per year based on NGL samples and results reported to the AOGCC. C. Each producing well will be tested at least once each month. Wells that have been shut-in and cannot meet the once -monthly test frequency must be tested within five days of startup. All available test separator capacity within the constraints imposed by operating conditions must be utilized for well testing. d. Optimum test duration and stabilization time will be determined on a well -by -well basis by the operator. Rule 9 Reservoir Pressure Monitoring a. An Annual Pressure Surveillance Plan shall be submitted to the AOGCC in conjunction with the Annual West Beach Oil Pool Reservoir Surveillance Report by June 15`h of each year. This plan will contain the number and approximate location of pressure surveys anticipated for the next calendar year and, unless AOGCC orders otherwise, the plan will be deemed approved 45 days after submission to AOGCC. b. Data from the surveys required in (a) of this rule shall be submitted with the Annual West Beach Oil Pool Reservoir Surveillance Report by June 15th of each year on Form 10-412. Data submitted shall include rate, pressure, time depths, temperature and any well condition necessary for the complete analysis of each survey. The datum for the pressure surveys is 8,800 true vertical feet subsea. Transient pressure surveys obtained by a shut- in build-up test, and injection well pressure fall-off test, a multirate test, or an interference test are acceptable. Calculation of bottom -hole pressures from surface data will be COs 207D.001, 311B.003, 317B.003, 329B.005, 345.002, 362A.006, 570.010 April 3, 2020 Page 6 of 12 permitted for water injection wells. Other quantitative methods may be administratively approved by the AOGCC. c. Results and data from any special reservoir pressure monitoring techniques, tests, or surveys shall also be submitted as prescribed in (b) of this rule. Rule 11 Administrative Action Upon proper application, or its own motion, and unless notice and public hearing are otherwise required, the AOGCC may administratively waive the requirements of any rule stated herein or administratively amend this order 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 aquifers. Pt. McIntyre and Stump Island Oil Pools — Conservation Order No. 317B Rule 4 Well Spacing There shall be no restrictions to well spacing within the affected area except that no pay may be opened in a well which is closer than 500 feet of an external property line where the owners and landowners are not the same on both sides of the line. Rule 10 Surface Commingling and Common Facilities a. Production from the Pt. McIntyre and Stump Island Oil Pools may be commingled at the surface with production from other pools for processing at the Lisburne Production Center ("LPC") and production from the Pt. McIntyre Oil Pool Drillsite PM2 may be commingled at the surface with production from other pools for processing at the Prudhoe Bay Unit IPA Gathering Center 1 ("GC I"), prior to custody transfer. b. Daily production from all wells will be based on empirical well performance curves derived from 3-phase flow equations and production well test data, and will be a function of flowing tubing pressure and gas -lift rate. The method is described within the "Prudhoe Bay Unit (PBU) Western Satellite Production Metering Plan — Policies and Procedures Document' dated August 1, 2002. c. Each producing well will be tested at least once each month. Wells that have been shut in and cannot meet the once -monthly test frequency must be tested within five days of startup. All available test separator capacity within the constraints imposed by operation conditions must be utilized for well testing. d. Optimum test duration and stabilization time will be determined on a well by well basis by the operator. e. Wells will use the associated process facility allocation factor for oil, gas, and water. Pt. McIntyre wells that flow to both GC 1 and LPC in the same month will use a prorated (GC 1 and LPC) well allocation factor for oil, gas, and water. f. Natural gas liquids ("NGLs") processed at the LPC will be allocated to each pool based on actual gas production volumes and NGL process simulations. Process simulations will be updated at least once per year based on NGL samples and results reported to the AOGCC. COs 20713.001, 31113.003, 31713.003, 32913.005, 345.002, 362A.006, 570.010 April 3, 2020 Page 7 of 12 g. NGLs attributable to the PM2 to GCI gas stream and recovered at the CGF will be allocated by calculating the amount of separator off -gas, excluding gas lift gas, attributable to Pt. McIntyre wells producing into GC -1. The percentage of total separator off -gas delivered to the CGF, that is Pt. McIntyre formation gas, multiplied by the total NGL recovery at CGF, yields the amount of NGLs to be allocated to Pt. McIntyre. h. Allocation data and well test data will be supplied to the AOGCC via the Annual Reservoir Surveillance Report. Rule 12 Reservoir Pressure Monitoring a. An Annual Pressure Surveillance Plan shall be submitted to the AOGCC in conjunction with the Annual Pt. McIntyre Oil Pool Reservoir Surveillance Report by June 15' of each year. This plan will contain the number and approximate location of pressure surveys anticipated for the next calendar year and, unless AOGCC orders otherwise, the plan will be deemed approved 45 days after submission to AOGCC. b. Data from the surveys required in (a) of this rule shall be submitted with the Annual Pt. McIntyre Oil Pool Reservoir Surveillance Report by June 15s' of each year on Form 10- 412. Data submitted shall include rate, pressure, time depths, temperature and any well condition necessary for the complete analysis of each survey. The datum for the pressure surveys is 8,800 true vertical feet subsea. Transient pressure surveys obtained by a shut-in build-up test, and injection well pressure fall-off test, a multirate test, or an interference test are acceptable. Calculation of bottom -hole pressures from surface data will be permitted for water injection wells. Other quantitative methods may be administratively approved by the AOGCC. c. Results and data from any special reservoir pressure monitoring techniques, tests, or surveys shall also be submitted as prescribed in (b) of this rule. Rule 14 Administrative Action Upon proper application, or its own motion, and unless notice and public hearing are otherwise required, the AOGCC may administratively waive the requirements of any rule stated herein or administratively amend this order 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 aquifers. Rule 16 Pt. McIntyre Oil Pool Enhanced Oil Recovery Proiect Injection of miscible injectant for enhanced recovery operations is approved for the Pt. McIntyre Pool. COs 207D.001, 311B.003, 317B.003, 329B.005, 345.002, 362A.006, 570.010 April 3,2020 Page 8 of 12 Niakuk Oil Pool — Conservation Order No. 329B Rule 3 Well Spacing There shall be no restrictions to well spacing within the affected area except that no pay may be opened in a well which is closer than 500 feet of an external property line where the owners and landowners are not the same on both sides of the line. Rule 6 Surface Commingling and Common Facilities a. Production from the Niakuk oil pool may be commingled on the surface with production from other pools for processing at the LPC prior to custody transfer. b. Production from each well will be determined by the following well test allocation methodology. Allocation data and well test data will be supplied to the AOGCC via the Annual Reservoir Surveillance Report. i. Conduct well tests to determine production rates for each well. ii. Calculate each well's theoretical monthly production (TMP) based on well test rate(s) and actual time on production. iii. Sum the TMP volume for all wells in all pools. iv. Determine an allocation factor as the ratio of the metered volume to the TMP for all wells in all pools (i.e., metered/TMP) v. Calculate each well's actual monthly production (AMP) volume as: AMP = TMP x Allocation Factor c. NGL's will be allocated to each pool based on actual gas production volumes and NGL process simulations. Process simulations will be updated at least once per year based on NGL samples and results reported to the AOGCC. d. Each producing well will be tested at least once each month. Wells that have been shut in and cannot meet the once -monthly test frequency must be tested within five days of startup. All available test separator capacity within the constraints imposed by operating conditions must be utilized for well testing. e. Optimum test duration and stabilization time will be determined on a well by well basis by the operator. Rule 8 Reservoir Pressure Monitorin a. An Annual Pressure Surveillance Plan shall be submitted to the AOGCC in conjunction with the Annual Niakuk Oil Pool Reservoir Surveillance Report by June 15th of each year. This plan will contain the number and approximate location of pressure surveys anticipated for the next calendar year and, unless AOGCC orders otherwise, the plan will be deemed approved 45 days after submission to AOGCC. COs 207D.001, 31113.003, 317B.003,329B.005, 345.002,362A.006,570.010 April 3, 2020 Page 9 of 12 b. Data from the surveys required in (a) of this rule shall be submitted with the Annual Niakuk Oil Pool Reservoir Surveillance Report by June 15Th of each year on Form 10-412. Data submitted shall include rate, pressure, time depths, temperature and any well condition necessary for the complete analysis of each survey. The datum for the pressure surveys is 8,800 true vertical feet subsea. Transient pressure surveys obtained by a shut-in build-up test, and injection well pressure fall-off test, a multirate test, or an interference test are acceptable. Calculation of bottom -hole pressures from surface data will be permitted for water injection wells. Other quantitative methods may be administratively approved by the AOGCC. c. Results and data from any special reservoir pressure monitoring techniques, tests, or surveys shall also be submitted as prescribed in (b) of this rule. Rule 12 Administrative Action Upon proper application, or its own motion, and unless notice and public hearing are otherwise required, the AOGCC may administratively waive the requirements of any rule stated herein or administratively amend this order 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 aquifers. North Prudhoe Bay Oil Pool — Conservation Order No. 345 Rule 5 Surface Commingling and Common Facilities a. Production from the North Prudhoe Bay Oil Pool may be commingled on the surface with production from other pools for processing at the LPC prior to custody transfer. b. Production from each well will be determined by the following well test allocation methodology. Allocation data and well test data will be supplied to the AOGCC via the Annual Reservoir Surveillance Report. 1. Conduct well tests to determine production rates for each well. 2. Calculate each well's theoretical monthly production (TMP) based on well test rate(s) and actual time on production. 3. Sum the TMP volume for all wells in all pools. 4. Determine an allocation factor as the ratio of the metered volume to the TMP for all wells in all pools (i.e., metered/TMP). 5. Calculate each well's actual monthly production (AMP) volume as: AMP = TMP x Allocation Factor c. NGLs will be allocated to each pool based on actual gas production volumes and NGL process simulations. Process simulations will be updated at least once per year based on NGL samples and results reported to the AOGCC. COs 20713.001, 311B.003, 317B.003, 32913.005, 345.002,362A.006, 570.010 April 3, 2020 Page 10 of 12 d. At a minimum, each producing well will be tested at least once each month. Wells that have been shut in and cannot meet the once -monthly test frequency must be tested within five days of startup. e. Optimum test duration and stabilization time will be determined on a well -by - well basis by the operator or, in its discretion, by the AOGCC. Rule 7 Reservoir Pressure Monitoring a. An Annual Pressure Surveillance Plan shall be submitted to the AOGCC in conjunction with the Annual North Prudhoe Bay Oil Pool Reservoir Surveillance Report by June 1511 of each year. This plan will contain the number and approximate location of pressure surveys anticipated for the next calendar year and, unless AOGCC orders otherwise, the plan will be deemed approved 45 days after submission to AOGCC. b. Data from the surveys required in (a) of this rule shall be submitted with the Annual North Prudhoe Bay Oil Pool Reservoir Surveillance Report by June 15" of each year on Form 10-412. Data submitted shall include rate, pressure, time depths, temperature and any well condition necessary for the complete analysis of each survey. The datum for the pressure surveys is 8,800 true vertical feet subsea. Transient pressure surveys obtained by a shut-in build-up test, and injection well pressure fall-off test, a multirate test, or an interference test are acceptable. Calculation of bottom -hole pressures from surface data will be permitted for water injection wells. Other quantitative methods may be administratively approved by the AOGCC. c. Results and data from any special reservoir pressure monitoring techniques, tests, or surveys shall also be submitted as prescribed in (b) of this rule. Rule 11 Administrative Action Upon proper application, or its own motion, and unless notice and public hearing are otherwise required, the AOGCC may administratively waive the requirements of any rule stated herein or administratively amend this order 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 aquifers. COs 207D.001, 31113.003, 317B.003, 329B.005, 345.002, 362A.006, 570.010 April 3, 2020 Page 11 of 12 Greater Pt. McIntyre Area — Conservation Order No. 362A.005 Rule 1: Lisburne Production Facilities Produced fluids from the Lisburne Oil Pool, West Beach Oil Pool, North Prudhoe Bay Oil Pool, Niakuk Oil Pool, Pt. McIntyre Oil Pool, Stump Island Oil Pool, and Raven Oil Pool may continue to be commingled on the surface for processing at the Lisburne Production Center. Production from each pool may be assigned on the basis of at least once monthly well tests using procedures described in individual conservation orders for those pools or in this order. The AOGCC may approve a different test frequency for individual wells upon application. Raven Oil Pool — Conservation Order No. 570 Rule 3: Well Snacin¢ There shall be no restrictions to well spacing within the affected area except that no pay may be opened in a well which is closer than 500 feet of an external property line where the owners and landowners are not the same on both sides of the line. Rule 6: Common Production Facilities and Surface Commin line a. Production from the Raven Oil Pool may be commingled on the surface with production from other pools for processing at the LPC prior to custody transfer. b. Production from each well will be determined by the following well test allocation methodology. Allocation data and well test data will be supplied to the AOGCC via the Annual Reservoir Surveillance Report. Conduct well tests to determine production rates for each well. ii. Calculate each well's theoretical monthly production (TMP) based on well test rate(s) and actual time on production. iii. Sum the TMP volume for all wells in all pools. iv. Determine an allocation factor as the ratio of the metered volume to the TMP for all wells in all pools (i.e., metered/TMP). v. Calculate each well's actual monthly production (AMP) volume as: AMP = TMP x Allocation Factor c. NGL's will be allocated to each pool based on actual gas production volumes and NGL process simulations. Process simulations will be updated at least once per year based on NGL samples and results reported to the AOGCC. d. Each producing well will be tested at least once each month. Wells that have been shut in and cannot meet the once -monthly test frequency must be tested within five days of startup. All available test separator capacity within the constraints imposed by operating conditions must be utilized for well testing. e. Optimum test duration and stabilization time will be determined on a well by well basis by the operator. COs 207D.001, 31113.003, 31713.003, 329B.005, 345.002, 362A.006, 570.010 April 3, 2020 Page 12 of 12 Rule 7: Reservoir Pressure Monitorin¢ a. An Annual Pressure Surveillance Plan shall be submitted to the AOGCC in conjunction with the Annual Raven Oil Pool Reservoir Surveillance Report by June 151 of each year. This plan will contain the number and approximate location of pressure surveys anticipated for the next calendar year and, unless AOGCC orders otherwise, the plan will be deemed approved 45 days after submission to AOGCC. b. Data from the surveys required in (a) of this rule shall be submitted with the Annual North Raven Oil Pool Reservoir Surveillance Report by June 15' of each year on Form 10-412. Data submitted shall include rate, pressure, time depths, temperature and any well condition necessary for the complete analysis of each survey. The datum for the pressure surveys is 9,850 true vertical feet subsea. Transient pressure surveys obtained by a shut-in build-up test, and injection well pressure fall-off test, a multirate test, or an interference test are acceptable. Calculation of bottom -hole pressures from surface data will be permitted for water injection wells. Other quantitative methods may be administratively approved by the AOGCC. c. Results and data from any special reservoir pressure monitoring techniques, tests, or surveys shall also be submitted as prescribed in (b) of this rule. DONE at Anchorage, Alaska and dated April 3, 2020. Jeremy M. Price Daniel T. Seamount. Jr. Jessie L. Chmielowski rasess-oeroo Jeremy M. Price Daniel T. Seamount, Jr. Jessie L. Chmielowski Chair, Commissioner Commissioner Commissioner As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not. included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Bernie Karl K&K Recycling Inc. Gordon Severson Penny Vadla P.O. Box 58055 3201 Westmar Cir. 399 W. Riverview Ave. Fairbanks, AK 99711 Anchorage, AK 99508-4336 Soldotna, AK 99669-7714 George Vaught, Jr. P.O. Box 13557 Denver, CO 80201-3557 Darwin Waldsmith P.O. Box 39309 Ninilchik, AK 99639 Richard Wagner P.O. Box 60868 Fairbanks, AK 99706 Es BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 20, 2020 Via USPS and Electronic Delivery Jeremy Price Commission Chair Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, AK 99501 D Re: Application for Administrative Approval Conforming PBU GPMA Pool Rules for Consistency Amendments to Conservation Orders: 207C, Rules 3, 9c, I Oa-f,16c; CO 317B Rules 4, 10b,d, 10g, 10h, 10i, 10j, 12a -f, 16b; CO 329A Rules 3, 6b,d, f -j, 8a -f, e; CO 311 B Rules 3, 7b, d, f -k; 9a -f; CO 345 Rules 5b,d,f-i, 7a -f; CO 362A.005 Rule 1; CO 570 (Corrected) Rule 3; AA No. 570.002; CO 570.004 Rule 6 b, d, f -i; , l Of governing the development and operation of the Lisburne, Pt. McIntyre, Niakuk, West Beach, North Prudhoe, and Raven Oil Pools Dear Chair Price, BP Exploration (Alaska) Inc. (BPXA), as the operator of the Prudhoe Bay Unit (PBU), respectfully requests that the commission administratively approve amendments described in this application to the referenced Conservation Orders. Each of these pools is in the Greater Pt. McIntyre Area (GPMA) in the PBU. This administrative relief is sought under Rule 17 of CO 207C and its equivalents in the other referenced Conservation Orders. The amendments are proposed with the goal of bringing more efficiency to the management of these reservoirs through achieving as much rule consistency as possible, while still honoring the unique aspects of each pool. More consistent rules will also result in easier monitoring of compliance for the Commission. The proposed changes are in line with recent Commission - approved changes to CO 341F (January, 2018) for the Prudhoe Oil Pool and for changes made to COs 452, 457B, 471, 484A, 505B for the Aurora, Borealis, Orion, Polaris and Midnight Sun Oil Pools (May 29, 2019). With the GPMA Plan Year running April 1 — March 31, BPXA RECEIVE® FEB 2 1 2020 1 AOGCC respectfully requests adjudication by April 1, 2020 in order that the entire next plan year may be under the new regulations. In overview*, BPXA seeks simplification and consistency for the following: Well Spacing. BPXA proposes there should be no restrictions as to well spacing except that no pay shall be opened in a well closer than 500 feet to the boundary of the affected area, unless the owner and landowner are the same on both sides of the line. This is consistent with the language for the Prudhoe Oil Pool except for the "same landowner" clause which represents an improvement to the POP rule. Pressure Data 10-412 Report. BPXA proposes to eliminate the monthly (Lisburne) to quarterly (Pt. McIntrye, Niakuk, West Beach) to unspecified (N Prudhoe and Raven) reporting requirement by allowing the operator to annually nominate in the ASR (or if no ASR is required to annually report) the number and approximate locations of pressure surveys, with the AOGCC having 30 days to register an issue; if none is raised the proposed number will take effect. The pressure data report would be included in the ASR with that report replacing Lisburne's requirement for an annual meeting to review pressure monitoring requirements and to discuss plans for reservoir management. All data necessary for analysis of each survey need not be submitted with the report but must be available to the commission upon request. This is the current regulation for the POP. It is proposed to remove the requirement to determine water volumes, annual API gravity, and annual gas samples from each non -gas lifted producing well in the Surface Commingling and Common Facilities rules as our reservoir recovery mechanisms are not changing. The need for data of this kind on such a frequency is not justified. If the operator were to change the recovery mechanism then it might be prudent to monitor each well in such a manner but barring that, BPXA does not see this data guiding reservoir management decisions. Allocation Process Reviews. BPXA proposes to formally eliminate this requirement. Instead, this requirement can be replaced with an Allocation Factor report in the Annual Surveillance Report (ASR). Well Test data Report. BPXA proposes to formally eliminate this requirement for all GPMA pools that currently have it and replace it with the Allocation Factor report in the ASR, as provided for other BP operated pools in AOGCC Administrative Approval (AA) (Docket # CO -15-013) dated 1/7/16. That AA waived the requirement to submit monthly reports of daily allocation and test data for a number of PBU pools. It covered some but not all of the GPMA Pools. Well Test Frequency. BPXA proposes to go from two to one per month for the GPMA pools. This will be in alignment with the other PBU pools. *Items that pertain solely to individual pools are: proposed elimination of the Lisburne Oil Pool Gas -Oil Ratio Test requirement, proposed upward revision of Injection Gradient and elimination of injection rate limit for the Lisburne Gas Cap Water Injection Project, and proposed elimination of the Pt. McIntyre Oil Pool EOR Project performance report. Rationale behind these "one-off' items is provided in Table 1, a spreadsheet containing all the proposed changes across the six GPMA pools. 4 The specific requests are detailed on an individual pool basis below using the convention of brackets [ ] for deletions of existing order words; use of underline denotes proposed new text. Only those rules and paragraphs within rules that have proposed changes are included below. Lisburne Oil Pool Conservation Order 207C Rule 3. WELL SPACING (Source: CO 2071 There shall be no restrictions as to well spacing except that no fThe well spacing unit shall be one producing well per governmental quarter section. No] pay shall be opened [in a well closer than 1,000 feet to the pay opened in another well or opened] in a well which is closer than 500 feet to the boundary of the affected area. [IM 1 a) Between 90 and 120 days after regular production commences and each six months thereafter a gas -oil ratio test will be taken on each well for as long as it produces oil; b) The gas -oil ratio tests will be for a minimum of four hours and shall be taken at the normal producing rate of the well; and c) The results of the gas -oil ratio tests will be reported on Form 10-409, Gas -Oil Ratio Test and will be submitted in January and July of each year.] a) [All new wells shall have an acceptable pressure survey, as defined in part (c), taken prior to regular production or injection. b) One pressure survey per producing drillsite per year shall be taken. Pressure surveys from producing or water and gas injection wells may be used for this pressure requirement. Pressure surveys covered in section (a) may be substituted for a drillsite pressure. c) Acceptable pressure surveys include static surveys, RFT/FMT, pressure buildup and falloff tests, and multi -rate pressure transient tests in production or injection wells. Other quantitative methods may be administratively approved by the Commission. d) The pressure datum for the Lisburne Oil Pool is 8900 feet subsea. The Commission may administratively amend this datum or create an additional datum when more information is available on the reservoir. e) Data from the pressure surveys, along with additional pressure data obtained through proper management of the reservoir, shall be filed on form 10-412 by the last day of the month following the month that the pressure survey was obtained. Submitted pressure data shall include other information as necessary such as rate, time, depth, temperature, and well conditions to allow for a complete analysis of the pressure survey. f) The operator shall schedule an annual meeting with the Commission to review the pressure monitoring program and discuss future plans for reservoir management.] 3 a. year. This plan will contain the number and approximate location of pressure surveys anticipated for the next calendar year, and it will be subject to approval by the AOGCC by July 15 of that year. b. Data from the surveys required in (a) of this rule shall be submitted with the Annual Lisburne Oil Pool Reservoir Surveillance Report by June 15 of each year on form 10-412. Data submitted shall include rate, pressure, time depths, temperature, and any well condition necessary for the complete analysis of each survey. The datum for the pressure surveys is 8,900 true vertical feet subsea. Transient pressure surveys obtained by a shut-in buildup test an injection well pressure fall-off test, a multirate test or an interference test are acceptable Calculation of bottom -hole pressures from surface data will be permitted for water injection wells. Other quantitative methods may be administratively approved by the AOGCC. c. Results and data from any special reservoir pressure monitoring techniques tests, or surveys shall also be submitted as prescribed in (b) of this rule. Rule 16, GAS -CAP WATER INJECTION PROJECT [b The Well L5-29 injection rate is limited to 20,000 barrels of water injected per day;] c.Injection pressures must be maintained below 0.85 psi/ft. Pt. McIntyre Oil Pool Conservation Order 317B Rule 4 Well Spacing There shall be no restrictions as to well spacing except that no [The spacing unit shall be one producing well per 40 acres or quarter -quarter governmental section. No] pay shall be opened in a well closer than 500 feet to the boundary of the affected area. Rule 10 Surface Commineline and Common Facilities b. Production from each well will be determined by the following well test allocation methodology. Allocation data and well test data will be supplied to the Commission [quarterly in both computer file and report formats.] via the Annual Reservoir Surveillance Report. No changes to the remainder of b (sub paragraphs). d. Each producing well will be tested at least [twice] once each month. Wells that have been shut in and cannot meet the [twice] once monthly test frequency must be tested within five days of startup. All available test separator capacity within the constraints imposed by operating conditions must be utilized for well testing. e The operator shall submit a review of pool production allocation factors and 0 issues over the prior year with the annual reservoir surveillance report and retain electronic file(s) containing daily allocation data and daily test data for a minimum of five years. Data shall be presented on a monthly basis, reported annually in the ASR. [1 Of) API gravity will be determined for each producing well annually by an API/MPMS approved method. 10g) Gas samples will be taken and analyzed for composition from each non -gas lifted producing well yearly. 10h) Quarterly allocation process reviews will be held with the Commission. 10i) This rule maybe revised or rewritten after an evaluation period of at least one year.] Rule 12 Reservoir Pressure Monitoring Ia. Prior to regular production, a pressure survey shall be taken on each well to determine the reservoir pressure. b. A minimum of one bottom hole pressure survey per producing governmental section shall be run annually. The surveys in part a. of this rule may be used to fulfill the minimum requirements c. The datum for all surveys is 8800' TVDss. d. Pressure surveys will be either a pressure buildup, pressure falloff, RIFT, or static bottom hole pressure after the well has been shut in for an extended period. e. The pressure surveys will be reported to the Commission quarterly. Commission form 10-412, Reservoir Pressure Report, shall be used to report results from these surveys. All data necessary for complete analysis of each survey need not be submitted with the form 10-412 but must be submitted upon request. f. Results and data from any special reservoir pressure monitoring techniques, tests, or surveys also shall be submitted in accordance with part e. of this rule.] year. This plan will contain the number and approximate location of pressure surveys anticipated for the next calendar year, and it will be subject to approval by the AOGCC by July 15 of that year. b.Data from the surveys required in (a) of this rule shall be submitted with the Annual Pt McIntyre Oil Pool Reservoir Surveillance Report by June 15 of each year on form 10- 412. Data submitted shall include rate pressure time depths temperature and any well condition necessary for the complete analysis of each survey. The datum for the pressure surveys is 8.800 true vertical feet subsea. Transient pressure surveys obtained by a shut- in buildup test, an injection well pressure fall-off test, a multirate test or an interference test are acceptable. Calculation of bottom -hole pressures from surface data will be permitted for water injection wells Other quantitative methods may be administratively approved by the AOGCC. c.Results and data from any special reservoir pressure monitoring techniques, tests, or surveys shall also be submitted as prescribed in (b) of this rule. Rule 16 Pt. McIntyre Oil Pool Enhanced Oil Recovery Project [b. An annual report must be submitted to the Commission detailing performance of the PMOP Enhanced Oil Recovery Project and outlining compositional information for the current miscible injectant necessary to maintain miscibility under anticipated reservoir conditions. The report should be submitted in conjunction with the PMOP Annual Reservoir Report.] Niakuk Oil Pool Conservation Order 329 Rule 3 Well Soacine [Upon application ofthe operator, the Commission may administratively approve the drilling of any well to a bottom hole location greater than 500 lineal feet from the external boundary of the affected area. No well bore may be open to the Niakuk oil pool within 500 feet of the external boundary of the affected area nor within 1000 feet of another well capable of producing from thesamepool.] There shall be no restrictions as to well spacing except that no pay shall be opened in a well closer than 500 feet to the boundary of the affected area. Rule 6 Surface Comminaling and Common Facilities b. Production from each well will be determined by the following well test allocation methodology. Allocation data and well test data will be supplied to the Commission [monthly in both computer file and report formats.] via the Annual Reservoir Surveillance Report. No changes to the remainder of b (sub paragraphs). d.Each producing well will be tested at least [twice] once each month. Wells that have been shut in and cannot meet the [twice] once monthly test frequency must be tested within five days of startup. All available test separator capacity within the constraints imposed by operating conditions must be utilized for well testing. [£Water volumes will be determined by API/MPMS approved methods, or the use of industry proven, on-line water cut measurement devices approved by the Commission. g.API gravity will be detennined for each producing well annually by an API/MPMS approved method. h.Gas samples will be taken and analyzed for composition from each non gas lifted 0 producing well yearly. i.Quarterly allocation process reviews will be held with the Commission. j.This rule may be revised or rewritten after an evaluation period of at least one year.] Rule 8 Reservoir Pressure Monitoring a. [Prior to regular production, a pressure survey shall be taken on each well to determine the reservoir pressure. b. A minimum of one bottom hole pressure survey per producing governmental section shall be obtained annually. The surveys in part'a' of this rule may be used to fulfill the minimum requirements. c. The datum for all surveys is 9200' TVDss. d. Pressure surveys will be either a pressure buildup, pressure falloff, RFT, or static bottom hole pressure after the well has been shut in for an extended period. e. The pressure surveys will be reported to the Commission quarterly on form 10-412, Reservoir Pressure Report. All data necessary for complete analysis of each survey need not be submitted with the form 10-412 but must be submitted upon request. f Results and data from any additional reservoir pressure tests, surveys or special monitoring techniques shall be submitted in accordance with part'e' of this rule.] This plan will contain the number and approximate location of pressure surveys anticipated for the next calendar year, and it will be subject to approval by the AOGCC by July 15 of that year. b. Data from the surveys required in (a) of this rule shall be submitted with the Annual Niakuk Oil Pool Reservoir Surveillance Report by June 15 of each year on form 10-412 Data submitted shall include ratepressure, time de the temperature, and any well condition necessary for the complete analysis of each survey. The datum for the pressure surveys is 8,800 true vertical feet subsea. Transient pressure surveys obtained by a shut- in buildup test, an injection well pressure fall-off test, a multirate test or an interference test are acceptable. Calculation of bottom -hole pressures from surface data will be permitted for water injection wells. Other quantitative methods may be administratively approved by the AOGCC. 7 c Results and data from any special reservoir pressure monitoring techniques, tests, or surveys shall also be submitted as prescribed in (b) of this rule. West Beach Oil Pool Conservation Order 311B Rule 3 Well Spacin¢ There shall be no restrictions as to well spacing except that no pay shall be opened in a well closer than 500 feet to the boundary of the affected area. [Statewide 160 -acre drilling units are in effect until such time as data or circumstances warrant the Commission to approve a change.] Rule 7 Common Facilities and Surface Comminalins [(b) Production from each pool will be determined by the following well test allocation method. Allocation data and well test data will be supplied to the Commission monthly in both computer file and report formats.] (d) Each producing well will be tested at least [twice] once each month. Wells that have been shut-in and cannot meet the [twice]once-monthly test frequency must be tested within five days of startup. All available test separator capacity within the constraints imposed by operating conditions must be utilized for well testing. [(f) Water volumes will be determined by API/MPMS approved methods, or the use of industry proven on-line water cut measurement devices. (g) API gravity will be determined for each producing West Beach well monthly. (h) Gas samples will be taken for each non -gas lifted producing well yearly. (i) Quarterly allocation process reviews will be held with the Commission. 0) Prior to installing separate test facilities (if required by future development) at West Beach, Commission approval of the facilities must be obtained. (k) This rule may be revised or rewritten after an evaluation period of at least one year.] Rule 9 Reservoir Pressure Monitorine [(a) Prior to regular production, a pressure survey shall be taken on each well to determine the reservoir pressure. (b)A minimum of one bottom -hole pressure survey per producing governmental section shall be run annually. The surveys in part (a) of this rule may be used to fulfill the minimum requirements. (c)The datum for all surveys is 8,800' TVD SS. (d)Pressure survey will be a pressure buildup, pressure falloff, RFT, or static bottom -hole pressure after the well has been shut in for an extended period. (e)The pressure surveys will be reported to the Commission quarterly. Commission form 10-412, Reservoir Pressure Report, shall be used to report results from these surveys. All data necessary for complete analysis of each survey need not be submitted with the form 10-412 but must be submitted on request. (i)Results and data from any special reservoir pressure monitoring techniques, tests, or surveys also shall be submitted in accordance with part (e) of this rule.] a. An Annual Pressure Surveillance Plan shall be submitted to the AOGCC in coniunction This plan will contain the number and approximate location of pressure surveyspated for the next calendar year, and it will be subject to approval by the AOGCC by July 15 of that b. Data from the surveys required in (a) of this rule shall be submitted with the Annual West Beach Oil Pool Reservoir Surveillance Report by June 15 of each year on form 10- 412. Data submitted shall include rate, pressure, time depths, temperature, and any well condition necessary for the complete analysis of each survey. The datum for the pressure surveys is 8,800 true vertical feet subsea. Transient pressure surveys obtained by a shut- in buildup test, an injection well pressure fall-off test, a multirate test, or an interference test are acceptable. Calculation of bottom -hole pressures from surface data will be permitted for water injection wells. Other quantitative methods may be administratively approved by the AOGCC. c. Results and data from any special reservoir pressure monitoringtechniques, chniques, tests, or surveys shall also be submitted as prescribed in (b) of this rule. North Prudhoe Bay Oil Pool Conservation Order 345 Rule 5 Surface Commingling and Common Facilities (b) Production from each well will be determined by the following well test allocation methodology. Allocation data and well test data will be supplied to the Commission via the Annual Reservoir Surveillance Report. [monthly in both computer file and report formats.] No changes to the remainder of b (sub paragraphs). (d) At a minimum, each producing well will be tested at least once [twice] each month. Wells that have been shut in and cannot meet the once [twice] monthly test frequency must be tested within five days of startup. [(f) Water volumes will be determined by API/MPMS approved methods, or the use of industry proven, on-line water cut measurement devices approved by the Commission. (g) API gravity will be determined for each producing well annually by an API/MPMS approved method. (h) Gas samples will be taken and analyzed for composition from each non -gas lifted producing well yearly. (i) The allocation process for the North Prudhoe Bay Oil Pool will be reviewed with the Commission in conjunction with scheduled LPC allocation review.] Rule 7 Reservoir Pressure Monitoring [7a) Prior to regular production, a pressure survey shall be taken on each well to determine the reserv0I r pressure. 0 7b) Until a secondary recovery project is approved and implemented, a minimum of one bottom- hole pressure survey per producing governmental section shall be obtained annually. 7c) The datum for all surveys is 9245'TVDss. 7d) Pressure surveys will be either a pressure buildup, pressure falloff, RFT, or static bottom- hole pressure after the well has been shut in for an extended period. 7e) The pressure surveys will be reported to the Commission on form 10-412, Reservoir Pressure Report. All data necessary for complete analysis of each survey need not be submitted with the form 10-412, but must be submitted upon request. 7f) Results and data from any additional reservoir pressure tests, surveys or special monitoring techniques shall be submitted in accordance with parte' of this rule.] year. This plan will contain the number and approximate location of pressure surveys anticipated for the next calendar year, and it will be subject to approval by the AOGCC by July 15 of that year. b.Data from the surveys required in (a) of this rule shall be submitted with the Annual North Prudhoe Bay Oil Pool Reservoir Surveillance Report by June 15 of each year on form 10-412. Data submitted shall include rate, pressure, time depths, temperature, and any well condition necessary for the complete analysis of each survey. The datum for the pressure surveys is 9245 true vertical feet subsea. Transient pressure surveys obtained by a shut-in buildup test, an injection well pressure fall-off test, a multirate test, or an interference test are acceptable. Calculation of bottom -hole pressures from surface data will be permitted for water injection wells. Other quantitative methods may be administratively approved by the AOGCC. c. Results and data from any special reservoir pressure monitoring techniques, tests, or surveys shall also be submitted as prescribed in (b) of this rule. Raven Oil Pool Conservation Order 570 Rule 3: Well Spacing [To allow for close proximity of wells in separate fault blocks, spacing within the pool will be a minimum of 20 acres. The ROP shall not be opened in any well closer than 500 feet to the external property lines where ownership or landownership changes.] 10 There shall be no restrictions as to well spacing except that no pay shall be opened in a well closer than 500 feet to the boundary of the affected area. Rule 10: Annual Reservoir Surveillance Report [f. By August 1 of each year, the Operator shall schedule and conduct a technical review meeting with the AOGCC to discuss the report contents and to review items that may require action within the coming year by the AOGCC. The AOGCC may conduct audits of technical data and analyses used in support of the surveillance conclusions and reservoir depletion plans.] Rule 6: Common Production Facilities and Surface Commingling c. All wells must be tested a minimum of [twice] once per month. The AOGCC may require more frequent or longer tests if the allocation quality deteriorates. Wells that have been shut in and cannot meet the [twice] once monthly test frequency must be tested within five days of startup. All available test separator capacity within the constraints imposed by operating conditions must be utilized for well testing. d. [The operator shall submit a monthly report and file(s) containing daily allocation data and daily test data for agency surveillance and evaluation.] Allocation data and well test data will be supplied to the Commission via the Annual Reservoir Surveillance Report. [f. Water volumes will be determined by API/MPMS approved methods, or the use of industry proven, on-line water cut measurement devices approved by the Commission. g.API gravity will be determined for each producing well annually by an API/MPMS approved method. h.Gas samples will be taken and analyzed for composition from each non gas lifted producing well yearly. i.Quarterly allocation process reviews will be held with the Commission.] Rule 7: Reservoir Pressure Monitoring a. [Prior to regular production or injection, an initial pressure survey must be taken in each well. b. A minimum of one pressure survey will be taken annually in each of the ROP reservoir compartments where production wells exist. C. The reservoir pressure datum will be 9,850' feet true vertical depth subsea. d. Pressure surveys may consist of stabilized static pressure measurements (bottom - hole or extrapolated from surface), pressure fall-off tests, pressure build-up tests, multirate tests, drill stem tests, and open -hole formation tests. e. Data and results from pressure surveys shall be submitted with the annual reservoir surveillance report. All data necessary for analysis of each survey need not be submitted with the report but must be available to the AOGCC upon request. f. Results and data from special reservoir pressure monitoring tests shall also be submitted in accordance with part (e) of this rule.] 11 a.An Annual Pressure Surveillance Plan shall be submitted to the AOGCC in conjunction with the Annual Raven Oil Pool Reservoir Surveillance Report by June 15th of each year. This plan will contain the number and approximate location of pressure surveys anticipated for the next calendar year, and it will be subject to approval by the AOGCC by July 15 of that year. b.Data from the surveys required in (a) of this rule shall be submitted with the Annual Raven Oil Pool Reservoir Surveillance Report by June 15 of each year on form 10-412. Data submitted shall include rate, pressure, time depths, temperature, and any well condition necessary for the complete analysis of each survey. The datum for the pressure surveys is 9,850' true vertical feet subsea. Transient pressure surveys obtained by a shut- in buildup test, an iniection well pressure fall-off test, a multirate test, or an interference test are acceptable. Calculation of bottom -hole pressures from surface data will be permitted for water injection wells. Other quantitative methods may be administratively approved by the AOGCC. c.Results and data from any special reservoir pressure monitoring techniques, tests, or surveys shall also be submitted as prescribed in (b) of this rule. If you have any questions regarding this request, please contact Bill Bredar at 564-5348 or through email at William.bredar@bp.com. Sincerely, q� Katrina Garner PBU Area Manager Cc: J. Schultz, CPAI J. Farr, ExxonMobil Alaska, Production Inc. D. White, Chevron USA D. Sturgis, ExxonMobil Alaska, Production Inc. E. Reinhold, CPAI D. Roby, AOGCC 12 Y —__ Table 1. GPMA Current vs. Proposed Conservation Order Changes (part of Application for Administrative Approval Conforming PBU GPMA Pool Rules for Consisting( 13abom. RewlwmrtCpmx Carn.mn MR[Regmmnmt euwgwci Rprrx.m.m CYnemwwte„eF cum OF. 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Itwkel MxcEmn MMwe d nY en[rmeeY mnamnien 4! n rnOnb DrM. 3o)BRnk9grnemaxsNmewellratinmowNM ,IF n r rem,w .SMY4m GORimwmmmn M. waewerrawemMmYomn,nmunion egnn mar j F.Mi dOiRW Tent Wtl -'mnWnY'rymr;eM Wetnam4n rrtnMwe. proWaa In n[uh44Mnbnranor _ m w.y.nelWyanmy... x4 _xq_ w '.w xn ir`p°rtwk In. pwunpnMMt M°rmelmn. _-.1- __ _ "_��mM,Ronmp. pgb ya"e.maedu R.bprmremd ion-fe.-Mono. dton M.hne". Mwrmmrwm. Rmnmoe, caw. Mmnbywkn RPL.mxlaW¢x9Yasdpw.m Mldti.nmmnheryerkNewnnlaemne anne, an r anotheMent I wdnlNenbn feet avu.' a91 Mn Mann. in w in oftmp�Copia. eeMOM MMM Me to Mane Mean° mfmr and ana°No- the - .an ane MFM', a,. r nMPm ^ImnrY_DM J - h^L5-39 Ya yP M, MI)Ir. and lo-. brjeeem me h 1110. web r M wan ml.edpa mr, and I Imkemn pmurn now M ma... Mbw 0 55 jog he nnueneortmutMwmnM.m tM C°mmMien nea6N MeMmrm W n d e PMO a.-OAa-, mFit m PralM ' 'MOMMIM mwa Pitioninlarmron for Manne. rrdlMMV MMr,mkipa.ry e thent loned an mined'. [orywnbhn-1 if. That" r F" nfnae ingrt on Yedwr nen m.. a, I the "-_- 1L1 no ParMen onNmelryenpnmeYmn Yreyued.. Prod.bnenana reswmemlMurna[CNIhe10 mNlm tlreymOneogrn rnPonO to ywmF oryNtr mn .gimme rebNe mawgmem. Nd env a Ymn ~5640 ~ . ~ STOF 0330 AFFIDAVIT $79.80 STATE OF ALASKA, ) THIRD JUDiCiAL DISTRICT. ) Eva M. Kaufmann being first duly sworn on oath deposes and says that he/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 a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on 1/19, 1996 OF PUBLICATION I NotiCe of Pobli~.H~ring~", STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The appl cation of Union, Oil Company of Ca fornio! (Unocal) for exception to 20t AAC 25.055 to allow drilling the J Granite Point No. 53 develop.' ment oil Well. . Unocal by letter dated/ January 12, 1996, has requested, an exception to the · provisions' of 20 AA(: 25.055(a) (3) for the drilling of o devel- 0Pment oil well'to the Middle K~noi oil POO n the GroniteJ Point 'Field 'l'ocoted in the Cook Inlet '.Basin, Southcentral A~aska. ', , The exception ' wou d allow / I.Unocal to d rectionally dr I | I the"G~'anite Point No, I oPment oil well to a producing I location that 'is closer than 500 Ifeet 'from a section'line Th~ surface location is ,"',south line and east · line 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. Subscribed and sworn to before ..... Lq ' . .................. ~):jj3.~ ............. ~9 ...... , li:30,,Pm,:on,,Fe 'in/confOrmance ,w,I : · · ',; 'calling the . i: ...... ~' ',:" · ',',fR:~;' (907) · ; '::" ': .... F-., :"uary 2~ 199,~ j If:no' Prbtest:is, filed ,tb~ I/'Co'mnJIsslon will ~o'nsider thi iSsuanCe ofthe Order w thout c hear rig,,, , :: I'f ;yOU., are a, person, with c disabil tY Who, may need c eh' ~lnl' ..l'. ? ' , ', ', , "~ -','',",'' " rder ": :'"'"" ' ': ;' , the ,', !;"'":' i "-'; ': ',; .' :;-" · :','ltac ,'laTer tr~an February 12 '*'9."{;~d ':: "' ' .'" n:'.' 1996. ,, :' :; .... '. "' .' .. ,missioh. r, VHI-, 12. ~ Com- ,o w/280 J, VHF, )repass, batter- ~ clean. ryochl, ~0 total tonics, ~7706 iet sk ~ $4,800. vonized er $750. eves. Pock , State 178-1559 r; Cus- beam, h, must 49. I. Less ~ Beaut 'Craft, , Maho- U0,000 ~.593.__j_~ eighter offer, ~lamil. ~ alum $30,000 ,., {9' ~5 tilt. oaded. Limo. ,11 for water, N hfs, '95 EZ , VHF, .$20,000 ~ turbo, ; hunt- aba. 88-14101 more, 1-3833 Mercury, galvanized trailer. ~320g. 345-36q 2 MUST SELL~ 18' Aluminum Air Boat, new 3,501 S650~. 696-5848 NEW Kolamath Alaskan w/40 hp Johnson tiller elec., trlr, & access. $6950 aba. 243-2353 '34 Northwlnd '74 (Uniflite mold) twin 340 Chryslers/ straight drives. Exc cond., survey & pictures avail,' re- duced $8,000 to S47,000 373.7446. '94 PARAGON/Grayling, 18ft, welded alum, powered by 4cyl Mercury outboad, 50/35hp, electric trim, oil inJ, Kenai riverboat, $12,500 or part true. 522-4271 ~' RACING Shell w/Sculls, :.~(1940's Vintage), $5000. ~' Call 276-4243. R'6UGHNECK, 17', iohnson tls jet, great river runner $]~000. aba 277-7293 ~.SACRIFICE~ E~Novy, 33 foot. Entirely remodeled, fully electronic. Sleeps 4. Has head, stave, open deck. Surveyed at $38,000 - m0ke offer. Call Ed for more inJormotion. Days, 522-1332. E~nings, 248-1719. 26; Seara¥ Sundance, re- pod/red in '93, sips 6, nw con- va~ top, oft cabin, complete svc rec, S18K. aba 248-0116 '91 27' SeasPort Pilot House THin Volvo wISP aD's, icebox, he~t, stove & oven, many ex- tros, exc cond. $62~000. 345-11.75 iSEASPORT 2200 XL, '90. .' GPS & more!. . $28,000. 345-8435 '94~SILVER STREAK with top, 20', Iow hours. 115 HP inboard turbo let. $16,500. 907;746-4948. 31' Silverton Glassply, Good For Charter Business, $45,000. Call. 248.9091 15' Smokercralt, 3$hp Yamaha let. Bilge pump. New bow cvr. Great boat. $4500 aba, 349-4483 rude, gan trailer, depth ' finder, CB, rod holders $3100 ' . 345-3612' Wo01dridge 20' 199:J rebuild. J. K. S. 349-1894. 5000 GVW Boat Trailer, tandem axle, brks, EZ load roller, painted, $1800 aba. 345-9376 25 HP HONDA outboard, long shaft, $2500. 349.7034 '79 35 bp. Johnson outboard w/new upper head & lower unit 1 yr old. $1250 aba. 344.0194 '92 9.9 H.P. MERC S.S., like new, $1100 firm. Call 272-1322. '94 40 hp Suzuki L/S, oil/ini, BO hfs, elc strt, oil controls, 2 yr wart. $2500. 376-6040 '85 JOHNSON 70 hp, w/SS prop, $2000. OUTBOARD let unit, for OMC 70bp, w/SS imp, $1000. 696-3342 Jeff. '96 MERC 135 Offshore OB. Used 6 wks. Like new. Not . priced new. $6600. 345-5070 " SUZUKI, 8 HP, LS, used less than 1 hour, $850 696-6959. 'Commercial ocean boat, deep Water plus, A Must For Alaskan Cessnas Parts Vberth, evinrude 140/15hp, easy S P O R T S M A N S T O L loader, galvanized tandem axle Air Repair 8, Maint. 258-7435 ~ Service trailer, $24~ooQ.._QBo 345-9800 visa & MC Welcome Aircraft Tundra oplionul..~13,Ouu. 9l.~.,~u ....... For classifications 815-890' please see today's AUTOMOTION section '75 185F, 1470TT, 460SMOH, King IFR, floats w/skis avail, L.R. fuel, Stol, 8/10. 243-0411 '18 PA-18-160, new 0.O Borer prop, 30" airstreak tires, part 135 operated. Ceconite recover '91, never on floats, standard wings, 4~0 hfs left on 1st run O/H by the Jug Shop. $40,000 aba. Coil: Sue 883-2225 Part-time Temporary Faculty Aviation Maintenance Technology Department Rural Delivery Program Requirements: FAA Airframe and Powerplant ratings. Inter. est or ability to teach in non- traditional settings, familiar with the challenges in rural !areas and multi-cultural Fishing 808 environments. ResPonsibilities: Prepare and P.W.S. Salmon Sein teach Aviation Mointencmce Permit, $50,000. (206)771-6399 Technology classes and labo- YAKUTAT Salmon Setnet rotaries in an FAA approved Permit 'S04D. Will sell w/ or program. Call (907)-276-3737. w/o baals/motors, gear, cabin. UAA is an AA/EO Employer 907.789-5656 and Educalional Institution. ,, 206 Performanc Sailboats 809 ' J-3 PRICE 5 Pass 6 seats, 1500//useful 30.5', '87, many hr car proof AF, great extras, sips 6, lots of electron- acft, $27,500. 376-6337 ics, $40,000 aba. 345-7523 SUPER Cub on cOnd, LRF, metal bell Aircraft 810 lots of extras. WHIP 6000 A better deal can't be had! W/Beaver rig. P.P. thru A.T.P./150s thru CALL: 235.7969' Twins. Qual. instr. 258-3247 ZANTOP Int'l Airlines Aircraft Coverings-Stits interviewing for exp'C mechanics qualified Polyfiber Fabric, P01ylone, L-188/P-3 aircraft on Aeorthane, Ceconite, Dope. Freight allowance, bush orders from 9am-Noon & welcome. Professional Paint. All qualified and in Visa & MC 562-65671-800-478-2641 per, sons should report' ~ ~ T ~ ~ Zantop's office at Cargo, 400 W. 50th Ave Eng., .Wing, Tail, W/S, nylon, Anchorage Airport mesh. New/used. Stoddards Aircraft Parls 272-2327 those hours. & Tailwheels, t GRA-AERO 26" ALASKA BUSH $1000 907.543.5225 LV SIGMA-TEK 'Vacuum 2YR-1000HR '15% OFF UNTIL ' ' 248-7070 C:185 seaplane . engine mount, cert $2500. (907) CUB FLAPS & A & P. Fiat Rate even ii damaged. 892-80?7 ori EDO FLOATS, 1 RIGGED FOR PACER,.' CALL: 376-1033. EPa 2000'S, PA-18 tight. Pump outs, ho: splashguards. $16K.. Fly-Lite 4000 hydraulic ski~, for 206. $16,50 745-2886. or 349-126! · .'/ ' LEGAL ~mphosls ~' the applicant's ability to "leverage" Federal funds with other sources of assistance. Applications for the AHFC grant match must be submitted no later than 4:30 p.m., Monday, March 11, 1996. AHFC will evaluate and priori. fize the funding requests. The highest ranked applicants will receive a Notice of Intent to Award from AHFC for inclusion in the USDA grant submission, For more information or to request on application package, contact: Kris Duncan, Planning Department 520 East 341h Avenue Anchorage, AK 99503 1-907-564-9206 or 1-800.478-2432 (toll.free) Public Notices ALASKA RAILROI CORPORATION PUBLIC MEETING N{ , , ' The Alaska Railroad Cm . lion, an independent, ~ i/c"'-q.oration of the Sta J ~a, announces it will I=.,./xt regular meeting ( ~,/~ of Directors on Jm 29,.]996~ in Anchorage, Al( The":tmeetlng will c0mme~ :'a,m;, on Januar at the Alaska Raih ration, 327 West Sh 'Avenue,. Anchorage 'he Planning Commission of ko, in the first floor BOard North Slope Borough will Room. . ' ' a public hearing at 9:30 ,, ,,..,..,,,~' .,~ , ,: ,, ,, ..., ,.,. .......... ~,, ,..~,,~.,,.. ~ PUBLIC The Planning Commission of the North Slope Borough will hold a public hearing at 9:30 A.M., January 26,.1996, at the Assembly Chambers of the North Slope Borough Adminis- tration Building, Borrow, Alaska 99723. The hearing is for the PUrpose of obtaining testimony regard- lng a Final Plat of Cakeater Road Right-of.Way Dedication, o subdivision of a portions Lot 1, U.S. Survey 5253, and portions of Sections 3, I0, & 15, Township 22 North, Range 18 West, Umiat Meridian, Alaska. Testimony regarding the pro- pose subdivision may be pres- ented at the Public Hearing. Written comments regarding the propose 'subdivision may AHFC complies with Title II of be presented to Sheldon the Americans with Disabilities Adams, Plotting Administra- Acl of 1990 and Rehabilitation tar, North Slope Borough, P.O. Act of 1973. Individuals with Box 69, Barrow, Alaska 99723. disabilities who may need All written comments should auxiliary aids or services or )e received Prior to 5:00 P.M., special ~:~l~.cotionS to apply January 25 1996 for et, hiS grant sl~o'L~l~,'~.contact )db' Jan '12-~5 1996 K,r~ Duncan at 1.800.478.2~32~no ~~F-~ later than February 5 so nec~'s~, pU~'~'i~'~i~A~i~iNG sory arrangements may be'":',)~, made. """ 'The J~lonning Commission of Pub.: Jan. 17 - 23, 1996 the ND.rth. Slope Borough will Notice of Public Hearing hold d~public hearing at 9:30 A.M., ~l~nuary 26, 1996, at the STATE OF ALASKA Assemb~/ Chambers of the Alaska Oil and Gas North Sl0~.. Borough Adminis- Conservation Comillission tration I~ilding, Barrow, Re: The application of Union Oil Company of California (Unocal) for exception to 20 AAC 25.055 to allow drilling the Granite' Point No. 53 develop- ment oil well. Unocal .by letter dated January 12, 1996, has requested an exception to the provisions of 20 AAC 25.055(a) (3) for the drilling of a devel. opment oil well to fha Middle Kenai oil pool in the Granite Point Field located in the Cook Inlet Basin, Southcentral Alaska. The exception would allow Unocal fo directionally drill the Granite Point NO. 53 devel- opment oil well to a producing location that is closer than 500 feet from a section line. The proposed surface location is 2855' from the south line and 3991' from the east line' of Section 13, T10N, R12W, Seward Meridian (SM) and the proposed bottom-hole location is 1177' from the south line and 408' from the west line o! Section 25, T10N, R12W, SM. A person who may be harm- ed if the requested order is issued may file a written protest prior.'to 4:00 PM February 2, 1996 with the Alaska Oil and Gas Conserva- tion Commission, ' 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and. raises a. substantial and material issue crucial to the~ Commission's determination, a hearing on the matter will be h~ld at the above address at 1:30 pm on February 20; 1996 in confo~'mance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling' the Commission's office, (907) 279-1433 after February 2, 1996. If no protest is filed, the Commission will consider the issuance of the order without a hearing. If you ore a person with a disability who may need o special modification in order to comment or to attend the public hearing, please contact Diana Fleck at 279.1433 no later than February 12, 1996. /s/David W. Johnston Commissioner Alaska Oil and Gas COnservation Commission. Pub~:, Jan. 18,. 1996 . PUBLIC HEARING Alaska 997~. . '[he hearincj~.is for the purpose of obtoining~!l'est imon y''~' regard- lng o Final,tPIot of Lots 1.& 2, E'maiksoun~eubdJvlsion, o sub- division d~ a portion at protracted~Sections 7 & 8, Township ~ North, Range 18 War~ '~'"':~,'t,x~"':":'~'~ located in .' ,.~ . '.' ',. 7 & 8, To~ ." .,~ '. .... :-ange 18 We.' . '.,I '.". , i Alaska. T~.~stJmon¥ ~.gardJng the pro- pose subdiglJlion may be pres- anted at tl~.~ Public Hearing. Written co~ents regarding the propos~'~subdivision may be prese.n~ed to Sheldon Adams, Pl~ting Administra- tor, North SJ~pe Borough, P.O. Box 69, Bo.r.~.t3w, Alaska 99723. All Written'i~omments should be received,~'ior to 5:00 P.M., January Pub.: Jan. ~1';) - 25, 1996 ~' NO' iCE OF PUBLI ;'HEARING , The Plannit I' Commission of the North S )Po Borough will hold a publ hearing at 9:30 A.AA., Janu~jl 26, 1996, at the Assembly ~ambers of fha North Slope'~;JBorough Adminis- tration B.~lding, Barrow, Alaska 997~i ' The hearing.ills for the purpose pf obtaJnJn~Jestimony regard- ing a prelir~Jnary Plat of Lots 1 thru 22, B~ck 66, Lots 1 thru 22, block 6]~,' Lots 1 thru 22, Block 68, L~,S 1 thru 22, Block 69 and Tra~'~.l and Tract 2.2, a resubdi~J~ion of Tract 2 Browervill~AddJtion //5, per Plat 91-16,~ecords of Barrow Recording .~.istrict, State of Alaska, Io~lted in Section 32 and 33, Tj~nship 23 North, Range'~Xlj? West, Umiat Meridiah, ~!osko.' Testimony~egarding the pro- pose subdi~J, sion may be pres- anted at tj~b' Public. Hearing. Written c~fnments regarding the propo~ subdivision may be pres~flted to Sheldon Adams, [gbtting Administro. tar, Nortl ~'Slope Borough, P.O. Box ~,9, f ~/rrow, Alaska 99723. All writt .fl comments should be racet,) id prior to 5:00 P.M., Jonuo~'; ~., 1996. Pub.~ JJ12- 25, 1996 . ~4~i~Jj _lC HEARING "' The ,__ ~m Commission o the ~ ~,iope Borough will hold a pubtic hearing at 9:30 A.M,, January 26, 1996, at the Assembly Chambers of the North Sit, ii,Borough Adminis. Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission ge~ The application of Union Oil Company of California (Unocal) for exception to 20 AAC 25.055 to allow drilling the Granite Point No. 53 development oil well. Unocal by letter dated January 12, 1996, has requested an exception to the provisions of 20 AAC 25.055(a)(3)for the drilling ora development oil well to the Middle Kenai oil pool in the Granite Point Field located in the Cook Inlet Basin, Southcentral Alaska. The exception would allow Unocal to directionally drill the Granite Point No. 53 development oil well to a producing location that is closer than 500 feet from a section line. The proposed surface location is 2855' from the south line and 3991' from the east line of Section 13, T10N, R12W, Seward Meridian (SM) and the proposed bottom-hole location is 1177' from the north line and 408' from the west line of Section 25, T10N, R12W, SM. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM February 2, 1996 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a heating on the matter will be held at the above adckess at 1:30 pm on February 20, 1996 in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433 after February 2, 1996. If no protest is filed, the Commission will consider the issuance of the order without a heating. 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 Diana Fleck at 279-1433 no later than February 12, 1996. ~ .. David Johnst~, Commissioner ~~_~ Alaska Oil and Gas Conservation Commission Published January 19, 1996 AO02614027 Unocal Corporati~~ Oil & Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL Kevin A. Tabler Land Manager Alaska Business Unit January 12, 1995 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Chairman Johnson: GRANITE POINT tt53 & 1154 ..REQUEST FOR SPACING EXCEPTION ADL 18761 andADL 374045 Union Oil Company of California (Unocal), as Operator of the Granite Point Field, requests your approva! to drill Granite Point # 54, ADL 18761 and further requests Administrative Approval, pursuant to Rule 7, for a spacing exception to Rule 2, Conservation Order No. 76. In triplicate, is our application for Permit to Drill Granite Point #54 (form 10-401) pursuant to 20 AAC 25.005 and our check No. 011161 in the amount orS100.00 as required under 20 AAC 25.005 (c) (1). Also enclosed, is Verification of Application by the Undersigned stating that applicant is acquainted with the facts. Granite Pt. #54 The specific location, interval and depth are as follows: 2480' FSL 1650' FEL Sec. 23, T10N-R12W, SM Top C-5 Producing Interval 60' FSL 2540' FEL Sec. 23, T10N-R12W, SM Bottom C-5 Producing Interval Also enclosed and submitted in triplicate is our application for Permit to Drill Granite Point #53, ADL 374045 (form 10-401) pursuant to 20 AAC 25.005 and our check No. ol 11/42 in the amount of $100.00 as required under 20 AAC 25.005 (c) (1). Verification of Application by the undersigned stating that applicant is acquainted with the l'acts pursuant to 20 AAC 25.055 (b)is attached as part of this application. JAN ! 1 96 It is requested that the Commision approve an exception to the statewide spacing regulation 20 AAC 25.055 (3) for the drilling of well Granite Point #53, ADL 374045 from the Granite Point Platform. Granite Pt. #53 The specific location, interval and depth are as follows: 1780' FSL 640' FWL Sec. 24, T10N-R12W, SM 600' FNL 490' FWL Sec. 25, T10N-R12W, SM Please note that once production is established in well #53 (since we have entered Sec. 25- -ADL 374045), this lease will be held by production. All applicable provisions of 20 AAC 25.050 (Deviation) have been met for each application and each owner and all operators of governmental quarter sections directly or diagonally offsetting the section where the oil wells are located have been notified by registered mail pursuant to 20 AAC 25.055 (b). A copy of said notification is attached hereto. If you require additional information, please contact Roxanne Sinz at (907) 263-7623 or Mitch Damm, Drilling Department at (907) 263-7679. We appreciate your review and trust the enclosed is satisfactory. V7 truly yours, ~' "%~'-----K evi n A.~Tabl~er~''c'- Enclosures