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Home My WebLink AboutAIO 017AREA INJECTION ORDER 17 Badami Oil Pool 1. June 4, 1998 Notice of Hearing, Publication, copy of bulk mailing list 2. July 1, 1998 BP's request for Area Injection Order 3. April 15, 1999 BP's request to inject Kekiktuk gas into the Badami Reservoir 4. September 27, 2004 Public Notice to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells 5. ------------------- Yearly reporting AREA INJECTION ORDER 17 - It e e STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: The APPLICA nON OF BP EXPLORATION (ALASKA) INe. ("BPXA") for an order allowing enhanced oil recovery injection in the Badami Oil Pool ) Area Injection Order No. 17 ) ) Badami Oil Pool ) Badami Field August 26, 1998 IT APPEARING THAT: 1. By letter dated June 1, 1998, BPXA requested authorization from the Alaska Oil and Gas Conservation Commission ("Commission") to inject fluids for the purposes of enhanced oil recovery ("EOR") in the Badami Oil Field. A meeting was also held at the Commission offices on March 23, 1998 to discuss the proposed development. 2. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on June 4, 1998. 3. The Commission did not receive any protest or request for a public hearing. FINDINGS: 1. Commission regulation, 20 AAC 25.460, provides authority to issue an order governing underground injection of fluids on an area basis for all wells within the same field, facility site, reservoir, project, or similar area. 2. BPXA is the sole operator of all wells within one-quarter mile of the area proposed for EOR operations. The State of Alaska is the surface owner. 3. The proposed EOR project will be conducted within the affected area for the Badami Oil Pool as defined in Conservation Order 402. 4. All ofthe formation waters below the permafrost in the Badami Oil Pool affected area are too saline to be considered freshwater, as defined by 20 AAC 25.570. 5. The Badami Oil Pool is defined as the accumulation of hydrocarbons common to and correlating with the interval between the measured depths of9,500 feet and 11,500 feet in the Badami # 1 well. 6. The Badami Oil Pool consists of a series of Canning Formation turbidite sandstones that are characterized by rapid changes in interval thickness, lithology, net sand and oil quality . 7. The Badami Oil Pool is confined above and below by thick sequences of impermeable Canning Formation marine shales. 8. Current development plans for the Badami Oil Pool consist oftwo phases. Phase one includes plans for 20 production wells, 15 injection wells, two shallow source water wells and one Class I waste disposal well. Phase two plans may include up to 24 additional wells. Future drilling results may significantly affect development plans for the Badami Oil Pool. Area Injection Order ~7 It Badami Oil Pool August 26, 1998 9. The depletion plan for the Badami Oil Pool entails maintaining pressure by replacing voidage. The four primary types of injection fluids will be source water, produced water, associated gas and imported miscible gas. Minor volumes of other Class II fluids that the Commission determines to be both incidental to the production of oil and gas and appropriate for use in enhanced oil recovery operations may also be injected. 10. The operator estimates that 6% to 8% of original oil in place (OOIP) in the Badami Oil Pool will be recovered with primary recovery methods, 12% to 20% OOIP with waterflood and, ultimately, 25% OOIP with a water-alternating-gas injection project. 11. The primary source of miscible fluids for the Badami EOR project will be the Endicott Oil Pool. e e Page 2 12. Maximum wellhead injection pressures for water and miscible gas is expected to be 3,500 psig and 5,500 psig, respectively. 13. Rock properties and fracture calculations indicate the sandstone intervals may fracture near the wellbore but the confining shales will not. Data indicate the confining shales have greater strength than the sands and expected injection pressures will not be great enough to fracture the shales. 14. Thermal effects of water injection and long-term reservoir pressure decline will tend to reduce the strength of the sand intervals lowering its fracture pressure. The impermeable, confining shales will not be affected and are expected to retain rock strength at or near their original fracture pressure. 15. The operator proposes to begin EOR operations no later than four months after first production. 16. Disposal injection for Class I wastes are authorized and governed by rules prescribed in Disposal Injection Order No. 12, AK-lIOO I-A, issued by the U.S. Environmental Protection Agency, Region 10, and waste disposal permit No. 963l-DB004 issued by the Alaska Department of Environmental Conservation. 17. The operator is required to drill wells within the proposed project area in accordance with 20 AAC 25.030 and to abandon wells in accordance with 20 AAC 25.105. 18. The mechanical integrity of injection wells must be demonstrated as specified in 20 AAC 25.412 prior to initiating injection operations. 19. The operator is required by 20 AAC 25.402 (d) & (e) to monitor tubing-casing annulus pressures of injection wells periodically during injection operations to ensure there is no leakage and that casing pressure remains less than 70% of minimum yield strength of the casmg. CONCLUSIONS: 1. Issuing an Area Injection Order in accordance with 20 AAC 25.402 is appropriate for the project area. The AIO will not cause waste or jeopardize correlative rights. 2. The Badami reservoir is incompletely delineated at this time and further well control may cause the currently proposed development plan to be substantively modified. 3. The proposed injection operations will occur in permeable strata that reasonably can be expected to accept injected fluids at pressures less than the fracture pressure of the confining strata. Area Injection Order ~7 e Badami Oil Pool August 26, 1998 e e Page 3 4. Enhanced recovery fluids will consist of source water, produced water, minor amounts of incidental Class II fluids; and associated and miscible gas, and are compatible with the receiving and confining zones. 5. All wells drilled within the proposed project area have been and will be constructed in accordance with 20 AAC 25.030 and abandoned in accordance with 20 AAC 25.105 or equivalent precursor regulation. 6. Well mechanical integrity must be demonstrated in accordance with 20 AAC 25.412 prior to initiation of injection operations. 7. A schedule must be developed which ensures that the mechanical integrity of each injection well is tested at least every four years after an initial test. 8. Tubing-casing annulus pressure and injection rates must be monitored at least weekly for disclosure of possible abnormalities in operational conditions. NOW, THEREFORE, IT IS ORDERED THAT Area Injection Order No. 17 be issued with the following rules governing Class II enhanced oil recovery injection operations in the following affected area: UMIAT MERIDIAN T9N T9N TlON TlON R19E R20E R19E R20E Section 1. Sections 2, 3, 4, 5, 6, 7, 8,9, 10, 11, 14, 15, 16, 17. Sections 24, 25 and 36. Sections 19, 29, 30, 31, 32, 33, 34, and 35. Rule 1 Authorized Injection Strata for Enhanced Recovery Within the affected area, fluids may be injected for purposes of pressure maintenance and enhanced recovery into strata defined as those which correlate with and are common to those found in the Badami #1 well between the measured depths of9,500 feet and 11,500 feet as stated in Conservation Order 402. Rule 2 Fluid Injection Wells The underground injection of fluids must be through a well permitted for drilling as a service well for injection in conformance with 20 AAC 25.005 or through a well approved for conversion to a service well for injection in conformance with 20 AAC 25.280. Rule 3 Monitoring the Tubing-Casing Annulus Pressure Variations The tubing-casing annulus pressure and injection rate of each injection well must be checked at least weekly to ensure there is no leakage and that it does not exceed a pressure that will subject the casing to a hoop stress greater than 70% of the casing's minimum yield strength. Area Injection Order N.7 e Badami Oil Pool August 26, 1998 e e Page 4 Rule 4 Reporting the Tubing-Casing Annulus Pressure Variations Tubing-casing annulus pressure variations between consecutive observations need not be reported to the Commission unless accompanied by a greater than 10% increase in injection rate, indicating possible tubing and casing leaks. Rule 5 Demonstration of Tubing-Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission that ensures that the tubing- casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi or 0.25 psi/ft. multiplied by the vertical depth ofthe packer, whichever is greater, but not to exceed a hoop stress greater than 70% ofthe minimum yield strength of the casing to be used. The test pressure must show stabilizing pressure and a decline of less than 10% within a thirty-minute period. The Commission must be notified at least twenty-four (24) hours in advance to enable a representative to witness pressure tests. Rule 6 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation and obtain Commission approval of a plan for corrective action and Commission approval to continue injection. Rule 7 Plugging and Abandonment ofIniection Wells An injection well located within the affected area must not be plugged or abandoned unless approved by the Commission. Well abandonment must be done in accordance with 20 AAC 25.105. Rule 8 Administrative Action Upon request, the Commission may administratively amend any rule stated above as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into a source of freshwater. Rule 9 Badami Oil Pool Annual Reservoir Report An annual Badami Oil Pool surveillance report will be required by April 1 of each year subsequent to commencement of enhanced oil recovery operations. The report shall include but is not limited to the following: a. Progress ofthe enhanced recovery project and reservoir management summary including engineering and geological parameters. b. Voidage balance by month of produced fluids and injected fluids. c. Analysis of reservoir pressure surveys within the pool. d. Results and where appropriate, analysis of production and injection logs, tracer surveys and observation well surveys. e. Results of any special monitoring. Area Injection Order N.7 . Badami Oil Pool August 26, 1998 ee Page 5 f. Evaluation of well testing and allocation. g. Future development plans. h. Review of Annual Plan of Operations and Development. DONE at Anchorage, Alaska and dated August 26, 1998 Robert N. Christenson, Commissioner r I . ~~ Camille Oechsli, Commissioner 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 ofthe 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 lO-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 fÌ'om the date on which the reQuest is deemed denied (i.e., 10th day after the application for rehearing was filed). G Aug 9, 2017 Mr. Dave Roby, Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3572 Subject: AIO 17 Yearly Reporting Dear Mr. Roby, RECEIVE AUG 10 2017 A Glacier Oil and Gas as owner/operator of Savant Alaska is providing the Commission an update to Area Injection Order (AIO) 17 dated Aug 26, 1998 that allows injection in the Badami oil pool for Enhanced Oil Recovery (EOR). Badami field has no been participating in enhanced oil recovery operations and produces minimum amounts of water. All water produced is injected in a Class I disposal well that is not completed in the interval for the Badami Oil Pool as defined in the AIO finding 5. All associated gas produced with the Oil is used as fuel gas on lease. Any excess gas produced is temporarily injected and retrieved in B 1-14 and B 1-21 during well cleanout operations, which occurs on a regular basis due to paraffin issues. Any minor make-up gas required is obtained via the 6" line between Endicott and Badami. Please see attachment 1 on these amounts for the year 2016. Glacier Oil and Gas will continue to update the Commission on the status of the AIO and will provide all information in Rule 9 of the AIO subsequent to commencement of EOR operations. I am available at your convenience to discuss this matter or provide additional information. Please don't hesitate to contact me at (907) 433-3822 or at d ascal glacieroil com 601 W. 5" Avenue, Suite 310, Anchorage, AK 99501 (907) 334-6745 Main (907) 334-6735 Fax Sincerely, �� Da ascal Pro uction Manager 31 cier Oil and Gas Attachments 1. 2016 Gas Breakdown and Oil Production Information 601 W. 5'" Avenue, Suite 310, Anchorage, AK 99501 (907) 334-6745 Main 1 (907) 334-6735 Fax 2016 Gas Breakdown and Oil Production Information Date Endicott te (imported) MMscf Gas Injection MMScf Fuel MMscf Flare MMscf Gas Production MMscf Oil Production bbls 01/01/2016 0.041 1.394 1.7014 0 3.054 1,191 01/02/2016 0.166 1.159 1.6912 0.0271 2.712 1,145 01/03/2016 0.012 1.149 1.685 0 2.821 1,128 01/04/2016 0.024 0.587 1.68421 0 2.247 1,176 01/05/2016 0.123 0.974 1.7551 0.0138 2.62 1,081 01/06/2016 0.064 0.973 1.6538 0.0079 2.571 1,193 01/07/2016 0.01 0.663 1.6558 0.0281 2.336 1,196 01/08/2016 0.006 0.884 1.6749 0 2.553 1,163 01/09/2016 0.026 0.735 1.6894 0 2.399 1169 01/10/2016 0.007 0.744 1.7204 01 2.457 1,162 01/11/2016 0.002 0.621 1.7244 0 2.343 1,140 01/12/2016 0.002 0.636 1.7211 0 2.355 1160 01/13/2016 0.003 0.853 1.7048 0 2.556 1,130 01/14/2016 0.001 0.644 1.7023 0 2.345 1,150 01/15/2016 0.036 0.668 1.6938 0.2037 2.529 1,137 01/16/2016 0.049 0 1.6904 0.3388 1.98 1,136 01/17/2016 0.005 0.289 1.7321 0.34067 1,103 01/18/2016 0.001 0 1.7775 0.34 2.112.356 1,135 01/19/2016 0 0.327 1.8232 0.2599 2.411 1,089 01/20/2016 0.061 0.264 1.815 0.1518 2.169 1,129 01/21/2016 0.002 0.7331 1.7767 0 2.508 1113 01/22/2016 0.001 0.941 1.7553 0 2.694 1109 01/23/2016 0.001 0.784 1.7533 0 2.536 1,155 01/24/2016 0.002 0.627 1.7822 0 2.407 1,155 01/25/2016 0.001 0.802 1.6932 0 2.494 1,133 01/26/2016 0.001 1.174 1.6844 0 2.857 1,147 01/27/2016 0.036 0.765 1.6755 0 2.405 1,139 01/28/2016 0.007 0.683 1.639 0 2.316 1,143 01/29/2016 0.007 0.913 1.672 01 2.577 1,132 01/30/2016 0.019 0.707 1.6926 01 2.381 1,021 01/31/2016 0.001 0.901 1.6908 01 2.591 1,251 02/01/2016 0.043 0.625 1.7202 01 2.303 1,132 02/02/2016 0.003 0.851 1.7276 0 2.576 1,049 02/03/2016 0.004 0.543 1.7172 0 2.256 1,128 02/04/2016 0 0.377 1.7667 0 2.143 1,093 02/05/2016 0.001 0.618 1.7584 0 2.376 1,065 02/06/2016 0.002 0.5731 1.8004 0 2.371 1,097 02/07/2016 0.002A0..'05 1.7373 0 2.412 1,079 02/08/2016 0.0031.7019 0 2.315 1116 02/09/2016 0.0141.69954O�.0268 2.425 1,094 02/10/2016 0.0091.6864 2.329 1,108 02/11/2016 01.6903 2.507 1,100 02/12/2016 0.0131.6623 2.335 1,101 02/13/2016 0.0031.6448 2.237 1,090 02/14/2016 0.004 0.748 1.6395 2.384 1,026 02/15/2016 0.003 0.862 1.6456 2.504 1,069 02/16/2016 0.045 0.79 1.6464 2.392 1,067 02/17/2016 0.023 0.768 1.6666 2.412 1,081 02/18/2016 0.009 0.764 1.6498 2.431 1072 02/19/2016 0.015 0.738 1.6548 ') An) , 7141 02/20/2016 0.001 0.544 1.6648 0.0067 2.215 1,003 02/21/2016 0.001 0.106 1.6803 0 1.785 862 02/22/2016 0.075 0.917 1.639 0.0435 2.524 887 02/23/2016 0.013 0.311 1.6199 0.0015 1.919 829 02/24/2016 0.06 0.668 1.6189 0 2.227 893 02/25/2016 0.087 0.674 1.6055 0 2.193 1,045 02/26/2016 0.015 0.673 1.6034 0 2.262 1,038 02/27/2016 0.004 0.5891 1.6141 0 2.199 1,045 02/28/2016 0.014 0.687 1.6304 0 2.303 1.044 02/29/2016 0.022 0.752 1.6326 0.0432 2.405 1,039 03/01/2016 0.021 0.67 1.6356 0 2.285 1,057 03/02/2016 0.019 0.545 1.6226 0 2.149 1,046 03/03/2016 0.026 0.728 1.6194 0 2.322 1,062 03/04/2016 0.004 0.592 1.6338 0 2.222 1,064 03/05/2016 0.002 0.702 1.6415 0.0104 2.352 1,067 03/06/2016 0.005 0.03 1.6651 0.0561 1.747 1.058 03/07/2016 0.006 0.471 1.6514 0 2.117 1,039 03/08/2016 0.017 0.57 1.627 0 2.18 1.053 03/09/2016 0 0.542 1.6405 0 2.182 1,061 03/10/2016 0.003 0.664 1.649 0 2.31 1,062 03/11/2016 0.048 0.569 1.637 0 2.159 1,048 03/12/2016 0.004 0.567 1.6593 0 2.222 1,048 03/13/2016 0.017 0.468 1.5919 0 2.043 1,048 03/14/2016 0 0.348 1.6662 0 2.014 1,066 03/15/2016 0 0.453 1.7104 0 2.163 1,061 03/16/2016 0.315 0.584 1.7683 0.1222 2.159 1,083 03/17/2016 0 0.1651 1.7563 0 1.921 961 03/18/2016 0 0.0391 1.7746 0 1.814 1,018 03/19/2016 0.001 0.0331 1.7649 0 1.797 1.028 03/20/2016 0.004 0.6121 1.7483 0 2.357 1.028 03/21/2016 0 0.321 1.75 0 2.071 1,056 03/22/2016 0 0.697 1.7336 0 2.431 1.052 03/23/2016 0.001 0.632 1.733 0 2.364 1,080 03/24/2016 0 0.721 1.7025 ol 2.423 999 03/25/2016 0.038 0.561 1.694 0 2.218 1,068 03/26/2016 0.047 0.802 1.6814 0 2.436 1,047 03/27/2016 0 0.394 1.7039 0 2.098 1,070 03/28/2016 0 0.643 1.723 0 2.366 1.059 03/29/2016 0 0.071 1.7802 0 1.851 1,054 03/30/2016 0 0.333 1.7859 0 2.119 1,052 03/31/2016 0 0.118 1.7849 0 1.903 1,057 04/01/2016 0.001 0.388 1.7779 0 2.165 1.059 04/02/2016 0.009 0.116 1.7277 0 1.835 1,067 04/03/2016 0.011 0.432 1.7106 0 2.131 1,044 04/04/2016 0.012 0.0021 1.6962 0 1.687 1,058 04/05/2016 0.053 0.2511 1.6837 0 1.883 1,024 04/06/2016 0.099 0.563 1.6799 0.0003 2.144 1,056 04/07/2016 0.086 0.406 1.671 0 1.991 1,035 04/08/2016 0.049 0.597 1.6425 0 2.19 1,030 04/09/2016 0.077 0.648 1.6383 0 2.209 1.046 04/10/2016 0.072 0.601 1.6364 0 2.166 1,046 04/11/2016 0.1 0.712 1.6437 0 2.256 1,039 04/12/2016 0.1011 0.637 1.6422 0 2.178 1,041 04/13/2016 0.0651 1.643 0 2.338 1.042 04/14/2016 0.0621 0.6061 1.6406 0 2.185 1046 04/15/2016 0.06 0.686 1.6947 6 2.321 1.021 04/16/2016 0.0831 0.5911 1.7003 0.0001 2.2081 1,043 04/17/2016 0.106 0.6791 1.6731 0 2.246 1,043 04/18/2016 0.089 0.598 1.718 0 2.227 1034 04/19/2016 0.102 0.758 1.7092 0 2.366 1010 04/20/2016 0.098 0.588 1.6426 0 2.133 937 04/21/2016 0.106 0.813 1.7068 0 2.414 .940 04/22/2016 0.111 0.759 1.6762 0 2.325 1188 04/23/2016 0.05 0.731 1.643 0 2.324 1,02 04/24/2016 0.008 0.646 1.6411 0 2.28 1,044 04/25/2016 0.141 0.884 1.6211 0.0112 2.375 1,048 04/26/2016 0.094 0.732 1.593 0 2.231 1042 04/27/2016 0.014 0.749 1.6418 0 2.377 1046 04/28/2016 0.019 0.635 1.6121 0 2.229 1,041 04/29/2016 0.069 0.751 1.5807 0.0697 2.332 1,039 04/30/2016 0.082 0.7111 1.5941 0 2.222 1,033 05/01/2016 0.069 0.8741 1.5988 0 2.403 989 05/02/2016 0.099 0.721 1.5942 0 2.217 1,032 05/03/2016 0.089 0.789 1.5956 0 2.296 1,010 05/04/2016 0.108 0.716 1.5965 0 2.204 1,028 05/05/2016 0.098 0.911 1.6123 01 2.425 1,009 05/06/2016 0.076 1.061 1.6121 0.0122 2.609 850 05/07/2016 0.085 1.562 1.6068 0 3.084 780 05/08/2016 0.18 0.487 1.621 0.2964 2.225 816 05/09/2016 0.115 0.9331 1.6172 0 2.435 1,108 05/10/2016 0.105 0.701 1.5988 0 2.195 1,106 05/11/2016 0.06 1.056 1.5818 0 2.578 1057 05/12/2016 0.046 0.734 1.5807 ol 2.269 1,072 05/13/2016 0.056 1.092 1.5838 0.0001 2.62 983 05/14/2016 0.028 0.742 1.5865 ol 2.3 1,061 05/15/2016 0.096 1.009 1.6028 0 2.516 1,038 05/16/2016 0.096 0.722 1.6056 0 2.231 1,069 05/17/2016 0.089 0.956 1.6035 0 2.47 1,037 05/18/2016 0.089 0.852 1.6004 0.0626 2.425 1066 05/19/2016 0.079 0.88 1.5844 0 2.386 1,036 05/20/2016 0.095 0.843 1.5902 0 2.337 1,059 05/21/2016 0.104 1.044 1.5767 ol 2.517 1,033 05/22/2016 0.075 0.764 1.5752 01 2.264 1,058 05/23/2016 0.107 0.967 1.5784 ol 2.438 1,034 05/24/2016 0.108 0.758 1.5744 0 2.224 1,057 05/25/2016 0.081 0.938 1.5773 0 2.435 1,036 05/26/2016 0.105 0.769 1.5784 0 2.243 1,054 05/27/2016 0.1 0.826 1.5835 0 2.309 1,040 05/28/2016 0.101 0.747 1.587 0 2.233 1,054 05/29/2016 0.093 0.966 1.5747 0 2.448 1,024 05/30/2016 0.1 0.769 1.5685 0 2.238 1058 05/31/2016 0.076 0.854 1.5589 0 2.337 1,041 06/01/2016 0.079 0.778 1.5619 ol 2.261 1,044 06/02/2016 0.296 0.917 1.6053 0 2.226 964 06/03/2016 0.077 1.086 1.5655 0 2.575 1,027 06/04/2016 0.044 1.175 1.5564 0 2.687 1,024 06/05/2016 0.006 1.061 1.5593 0 2.614 1,038 06/06/2016 0.158 0.82 1.593 0 2.255 1,006 06/07/2016 0.391 1.192 1.6287 0 2.429 1,034 06/08/2016 0.259 1.231 1.6109 0 2.583 1,010 06/09/2016 0.005 1.442 1.57]6 0 3.008 1,054 06/10/2016 0.06 1.336 1.58081 01 2.857 976 06/11/2016 0.077 1.266 1.5443 0 2.734 1020 06/12/2016 0.049 1.808 1.5305 0 3.289 1,008 06/13/2016 0.037 1.468 1.5348 0 2.966 1,021 06/14/2016 0.066 1.464 1.57 0 2.969 989 06/15/2016 0.052 1.228 1.5577 0 2.734 1,012 06/16/2016 0.067 1.501 1.5828 0.0003 3.017 1005 06/17/2016 0.065 1.4751 1.5764 Ol 2.987 931 06/18/2016 0.054 2.0281 1.5481 0.0002 3.522 1019 06/19/2016 0.084 1.527 1.5796 0 3.022 1,045 06/20/2016 0.068 0.253 1.5751 0 1.759 1,087 06/21/2016 0.016 0 1.5939 0 1.578 1115 06/22/2016 0.061 0.568 1.6031 0 2.11 1,084 06/23/2016 0.075 0.429 1.5815 0 1.935 1,125 06/24/2016 0.057 1.671 1.5393 0 3.153 838 06/25/2016 0.046 2.33 1.5588 0 3.843 488 06/26/2016 0.062 2.0211 1.567 0.0004 3.526 599 06/27/2016 0.053 1.6321 1.5518 0 3.131 775 06/28/2016 0.015 2.5551 1.5141 0.0003 4.054 956 06/29/2016 0.078 1.146 1.564 0 2.632 1,000 06/30/2016 0.076 1.539 1.5642 0.0002 3.027 985 07/01/2016 0.077 1.993 1.5539 0 3.47 982 07/02/2016 0.041 1.206 1.5346 0 2.699 981 07/03/2016 0.074 1.319 1.5293 0 2.774 979 07/04/2016 0.072 1.378 1.5531 0 2.859 981 07/05/2016 0.189 1.375 1.5582 0.0746 2.82 1,233 07/06/2016 0.192 2.351 1.5535 0 3.712 709 07/07/2016 0.094 2.304 1.5485 0 3.759 712 07/08/2016 0.082 2.877 1.5595 0 4.355 741 07/09/2016 0.128 2.464 1.5346 0.0023 3.873 982 07/10/2016 0.105 1.633 1.5134 0 3.042 958 07/11/2016 0.087 1.084 1.523 0.0019 2.522 1,344 07/12/2016 0.083 1.672 1.5017 0.0026 3.093 1,110 07/13/2016 0.08 1.944 1.4921 0.0034 3.36 972 07/14/2016 0.043 2.986 1.4768 0.002 4.422 986 07/15/2016 0.033 2.63 1.4863 0.0004 4.083 977 07/16/2016 0.062 2.285 1.5072 0 3.73 979 07/17/2016 0.098 1.771 1.5222 0 3.195 1,008 07/18/2016 0.092 1.025 1.5447 0.0002 2.478 970 07/19/2016 0.083 0.746 1.5648 0.0005 2.229 974 07/20/2016 0.051 1.145 1.5514 0.0011 2.646 960 07/21/2016 0.071 0.738 1.5387 0.00061 2.206 991 07/22/2016 0.109 0.982 1.5542 0 2.427 982 07/23/2016 0.136 0.571 1.5571 0 1.992 969 07/24/2016 0.158 0.373 1.555 0 1.771 1,117 07/25/2016 0.071 0.387 1.5436 0 1.859 1,067 07/26/2016 0.065 0.914 1.5313 0 2.38 1,016 07/27/2016 0.028 1.195 1.4947 0 2.661 1,042 07/28/2016 0.036 1.306 1.5165 0 2.787 959 07/29/2016 0.021 1.064 1.53 0 2.573 996 07/30/2016 0.026 1.204 1.5142 0 2.692 1,000 07/31/2016 0.012 1.197 1.516 0 2.7 1,019 08/01/2016 0.104 1.235 1.4873 0.0705 2.689 949 08/02/2016 0.019 1.153 1.5239 0 2.658 1,001 08/03/2016 0.054 1.0761 1.549 0 2.572 1,001 08/04/2016 0.075 1.071 1.5506 0 2.547 734 08/05/2016 0.086 1.1471 1.5519 ol 1188 08/06/2016 0.081 1.032 1.5297 0 2.481 1,015 08/07/2016 0.069 1.231 1.5169 0 2.678 1,004 08/08/2016 0.068 1.189 1.5191 0 2.64 1,003 08/09/2016 0.03 1.162 1.526 0 2.657 110-0-2- 00208/10/2016 08/10/2016 0.063 1.055 1.5395 0 2.532 1,000 08/11/2016 0.087 1.197 1.5506 0 2.66 994 08/12/2016 0.079 0.931 1.5417 0 2.394 1,003 08/13/2016 0.059 1.107 1.5403 0 2.588 992 08/14/2016 0.08 0.939 1.5272 0.3707 2.756 1,003 08/15/2016 0.028 1.132 1.5905 0 2.695 975 08/16/2016 0.014 0.929 1.5805 0 2.496 997 08/17/2016 0.003 1.156 1.5657 0 2.719 974 08/18/2016 0.001 1.07 1.581 0 2.651 988 08/19/2016 0.051 1.218 1.5726 0 2.739 957 08/20/2016 0.052 1.039 1.5721 0 2.56 1.007 08/21/2016 0.077 1.405 1.5681 0.0002 2.897 971 08/22/2016 0.065 1.022 1.5762 0 2.533 988 08/23/2016 0.072 1.099 1.5824 0 2.609 977 08/24/2016 0.072 1.009 1.565 0 2.502 987 08/25/2016 0.044 1.269 1.5732 0 2.797 925 08/26/2016 0.059 0.847 1.5908 0 2.378 976 08/27/2016 0.062 1.068 1.5979 0 2.604 960 08/28/2016 0.033 0.764 1.614 0 2.345 948 08/29/2016 0.065 0.917 1.658 0 2.51 985 08/30/2016 0.05 0.853 1.6345 0 2.438 987 08/31/2016 0.023 0.937 1.6242 0 2.539 983 09/01/2016 0.063 0.814 1.6307 0 2.381 991 09/02/2016 0.018 0.945 1.6328 0 2.56 986 09/03/2016 0.021 0.812 1.6269 0 2.417 986 09/04/2016 0.022 0.871 1.6101 0 2.459 917 09/05/2016 0.037 0.752 1.623 0 2.338 951 09/06/2016 0.02 0.946 1.6365 0 2.562 955 09/07/2016 0.02 0.726 1.6444 0 2.35 963 09/08/2016 0.009 0.841 1.6268 0 2.46 955 09/09/2016 0.002 0.749 1.6152 0 2.363 950 09/10/2016 0.037 1.006 1.6099 0 2.579 863 09/11/2016 0.029 0.727 1.6256 0 2.324 919 09/12/2016 0.092 0.854 1.6284 0 2.39 878 09/13/2016 0.091 0.736 1.6185 0 2.264 911 09/14/2016 0.055 0.985 1.6216 0 2.552 882 09/15/2016 0.035 0.846 1.6256 0 2.436 877 09/16/2016 0.02 0.947 1.6165 0 2.543 877 09/17/2016 0.005 0.742 1.5977 0 2.335 905 09/18/2016 0.113 1.232 1.618 0.0175 2.755 847 09/19/2016 0.04 0.814 1.5573 0.0315 2.362 911 09/20/2016 0.021 1.0411 1.5315 0 2.551 920 09/21/2016 0.038 0.808 1.5087 0 2.279 902 09/22/2016 0.03 0.997 1.5452 0 2.512 875 09/23/2016 0.003 0.898 1.561 0 2.456 919 09/24/2016 0.005 1.017 1.5806 0 2.593 910 09/25/2016 0.013 0.902 1.5902 0 2.478 910 09/26/2016 0.001 0.928 1.6021 0.0001 2.529 900 09/27/2016 0.012 1.318 1.6117 0.0001 2.917 892 09/28/2016 0.0121 1.131 1.595 0.0003 2.714 914 09/29/2016 0.0051 0.7551 1.5824 0 2.332 914 09/30/2016 0.021 0.7721 1.5783 01 2.33 930 10/01/2016 0.214 0.663 1.5774 0.0858 2.112 884 10/02/2016 0.048 0.918 1.5856 0.019 2.475 874 10/03/2016 0.029 0.988 1.6911 0.019 2.669 902 10/04/2016 0.001 0.744 1.6152 0.1362 2.494 900 10/05/2016 0.028 0.262 1.6007 0.1769 2.011 901 10/06/2016 0.1 0.625 1.6173 0.0627 2.205 844 10/07/2016 0.138 0.836 1.6164 0 2.315 868 10/08/2016 0.102 0.9571 1.5981 0 2.453 882 10/09/2016 0.096 0.57 1.5934 0 2.067 886 10/10/2016 0.07 0.858 1.634 0.0004 2.423 875 10/11/2016 0.081 0.506 1.6208 0.0004 2.046 883 10/12/2016 0.094 0.871 1.6093 0 2.387 878 10/13/2016 0.095 0.722 1.6078 0.0001 2.235 878 10/14/2016 0.09 0.83 1.6121 0.0005 2.353 899 10/15/2016 0.034 0.763 1.5787 0.0104 2.318 889 10/16/2016 0.058 0.769 1.619 0.0025 2.332 878 10/17/2016 0.024 0.718 1.6418 0.0002 2.336 884 10/18/2016 0.003 0.792 1.6433 0.0007 2.433 811 10/19/2016 0.019 0.7 1.6644 0.0006 2.346 753 10/20/2016 0.005 0.869 1.6524 0.0019 2.518 851 10/21/2016 0.005 0.722 1.6243 0 2.341 843 10/22/2016 0.015 0.788 1.6238 0.0002 2.397 1,038 10/23/2016 0.002 0.74 1.6236 0 2.362 904 10/24/2016 0.008 0.752 1.677 0 2.422 889 10/25/2016 0.022 0.674 1.6398 0 2.291 893 10/26/2016 0.006 0.703 1.624 0 2.321 893 10/27/2016 0.029 0.578 1.6307 0 2.18 857 10/28/2016 0.008 0.621 1.6648 0.0005 2.278 872 10/29/2016 0.053 0.579 1.6282 0 2.154 884 10/30/2016 0.138 0.752 1.6127 0.0171 2.244 876 10/31/2016 0.021 0.644 1.6242 0.0002 2.248 891 11/01/2016 0.004 0.64 1.6542 0 2.29 872 11/02/2016 0.036 0 1.6278 0 1.592 888 11/03/2016 0.01 0.481 1.6406 0 2.111 868 11/04/2016 0.005 0.587 1.6427 0 2.225 884 11/05/2016 0.017 0.838 1.6649 0 2.486 877 11/06/2016 0 0.572 1.7288 0.0009 2.302 936 11/07/2016 0.002 0.722 1.6719 0.0009 2.392 876 11/08/2016 0.004 0.557 1.6419 0.0009 2.196 885 11/09/2016 0.004 0.616 1.6401 0 2.252 857 11/10/2016 0.021 0.548 1.65161 0 2.178 874 11/11/2016 0.026 0.472 1.6343 0.0017 2.081 858 11/12/2016 0 0.003 1.6338 0 1.637 870 11/13/2016 0.025 0.155 1.6339 0 1.764 876 11/14/2016 0.036 0.501 1.607 0.0002 2.073 634 11/15/2016 0.008 0.353 1.6584 0.001 2.005 1,028 11/16/2016 0.001 0.479 1.6878 0.0014 2.167 979 11/17/2016 0.004 0.371 1.6631 0 2.029 852 11/18/2016 0.002 0 1.6604 0 1.658 1,226 11/19/2016 0 0.421 1.6366 0 2.057 1,017 11/20/2016 0 0.482 1.6865 0 2.168 1,015 11/21/2016 0 0.849 1.6729 0.0003 2.521 1,033 11/22/2016 0.042 0.483 1.663 0.2138 2.318 1,013 11/23/2016 0.029 0.418 1.686 0 2.075 991 11/24/2016 0 0 1.683 0 1.683 1049 11/25/2016 0 0.24 1.69651 511.936 970 11/26/2016 0 0 1.6905 0 1.69 1,039 11/27/2016 0.004 0.314 1.6918 0 2.002 995 11/28/2016 0 0 1.6992 0 1.699 1,020 11/29/2016 0.005 0.222 1.728 0 1.945 980 11/30/2016 0 0 1.7438 0 1.744 1,005 12/01/2016 0.011 0.155 1.7414 0 1.885 997 12/02/2016 0 0.039 1.7184 0 1004 12/03/2016 0 0.205 1.7476 0 981 12/04/2016 0 0 1.7651 0 984 12/05/2016 0 0.12 1.7695 0 d967 965 12/06/2016 0 0 1.7729 0 979 12/07/2016 0 0.044 1.779 0 967 12/08/2016 0 0 1.7813 0 . 12/09/2016 0.001 0.096 1.7713 0 1.866 985 12/10/2016 0 0 1.729 0 1.729 975 12/11/2016 0.001 0.033 1.7255 0 1.758 957 12/12/2016 0 0 1.7112 0 1.711 977 12/13/2016 0.025 0.073 1.6986 0 1.747 896 12/14/2016 0.016 0 1.7264 0 1.711 921 12/15/2016 0.007 0.255 1.7206 0 1.969 949 12/16/2016 0.032 0 1.6567 0 1.625 951 12/17/2016 0.051 0.143 1.6562 0.0005 1.748 930 12/18/2016 0.035 0 1.6772 0.001 1.643 959 12/19/2016 0.005 0.323 1.6699 0 1.988 941 12/20/2016 0 0 1.697 0 1.697 948 12/21/2016 0 0.101 1.6906 0 1.792 939 12/22/2016 0 0 1.7058 0 1.706 942 12/23/2016 0.029 0.141 1.7084 0 1.82 932 12/24/2016 0 01 1.7232 0 1.723 940 12/25/2016 0.001 0.189 1.6853 0 1.873 937 12/26/2016 0.003 0 1.717 0 1.714 938 12/27/2016 0.001 0.196 1.7323 0 1.927 921 12/28/2016 0 0 1.7567 0 1.757 935 12/29/2016 0.023 0.171 1.74231 0 1.89 928 12/30/2016 0.028 0 1.6774 0 1.649 934 12/31/2016 0.011 0.254 1.6615 0 1.904 890 C Aug 9, 2017 Mr. Dave Roby, Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3572 Subject: AIO 17 Yearly Reporting Dear Mr. Roby, RECEIVEf) AUG 10 P017 AOGCC Glacier Oil and Gas as owner/operator of Savant Alaska is providing the Commission an update to Area Injection Order (AIO) 17 dated Aug 26, 1998 that allows injection in the Badami oil pool for Enhanced Oil Recovery (EOR). Badami field has no been participating in enhanced oil recovery operations and produces minimum amounts of water. All water produced is injected in a Class I disposal well that is not completed in the interval for the Badami Oil Pool as defined in the AIO finding 5. All associated gas produced with the Oil is used as fuel gas on lease. Any excess gas produced is temporarily injected and retrieved in B1-14 and B1-21 during well cleanout operations, which occurs on a regular basis due to paraffin issues. Any minor make-up gas required is obtained via the 6" line between Endicott and Badami. Please see attachment 1 on these amounts for the year 2016. Glacier Oil and Gas will continue to update the Commission on the status of the AIO and will provide all information in Rule 9 of the AIO subsequent to commencement of EOR operations. I am available at your convenience to discuss this matter or provide additional information. Please don't hesitate to contact me at (907) 433-3822 or at dpascal@glacieroil.com 601 W.5" Avenue, Suite 310, Anchorage, AK 99501 (907) 334-6745 Main 1 (907) 334-6735 Fax Sincerely, YVjj- Pascaler s Attachments 1. 2016 Gas Breakdown and Oil Production Information 601 W. 5" Avenue, Suite 310, Anchorage, AK 99501 (907) 334-6745 Main (907) 334-6735 Fax 2016 Gas Breakdown and Oil Production Information Date Endicott (imported) MMscf Gas Injection MMScf Fuel MMscf Flare MMscf Gas Production MMscf Oil Production bbls 01/01/2016 0.041 1.394 1.7014 0 3.054 1,191 01/02/2016 0.166 1.159 1.6912 0.0271 2.712 1,145 01/03/2016 0.012 1.149 1.685 0 2.821 1,128 01/04/2016 1 0.024 0.5871 1.6842 0 2.2471 1,176 01/05/2016 0.123 0.9741 1.7551 0.0138 2.62 1,081 01/06/2016 0.064 0.973 1.6538 0.0079 2.571 1,193 01/07/2016 0.01 0.663 1.6558 0.0281 2.336 1,196 01/08/2016 0.006 0.884 1.6749 0 2.553 1,163 01/09/2016 0.026 0.735 1.6894 0 2.399 1,169 01/10/2016 0.007 0.744 1.7204 0 2.457 1,162 01/11/2016 0.002 0.62 1.7244 01 2.343 1,140 01/12/2016 0.002 0.636 1.7211 0 2.355 1,160 01/13/2016 0.003 0.8531 1.7048 0 2.556 1,130 01/14/2016 0.001 0.6441 1.7023 0 2.345 1,150 01/15/2016 0.036 0.6681 1.6938 0.2037 2.529 1137 01/16/2016 0.049 01 1.6904 0.3388 1.98 1,136 01/17/2016 0.005 0.2891 1.7321 0.3406 2.357 1,103 01/18/2016 0.001 01 1.7775 0.34 2.116 1,135 01/19/2016 0 0.327 1.8232 0.2599 2.411 1,089 01/20/2016 0.061 0.264 1.815 0.1518 2.169 1,129 01/21/2016 0.002 0.733 1.7767 0 2.508 1,113 01/22/2016 0.001 0.94 1.7553 0 2.694 1,109 01/23/2016 0.001 0.784 1.7533 0 2.536 1,155 01/24/2016 0.002 0.627 1.7822 0 2.407 1,155 01/25/2016 0.001 0.802 1.6932 0 2.494 1,133 01/26/2016 0.001 1.174 1.6844 0 2.857 1,147 01/27/2016 0.036 0.765 1.6755 0 2.405 1,139 01/28/2016 0.007 0.683 1.639 0 2.316 1,143 01/29/2016 0.007 0.913 1.672 0 2.577 1,132 01/30/2016 0.019 0.707 1.6926 0 2.381 1,021 01/31/2016 0.001 0.9011 1.6908 0 2.591 1,251 02/01/2016 0.043 0.6251 1.7202 0 2.303 1,132 02/02/2016 0.003 0.8511 1.7276 0 2.576 1,049 02/03/2016 0.004 0.543 1.7172 0 2.256 1,128 02/04/2016 0 0.377 1.7667 0 2.143 1,093 02/05/2016 0.001 0.618 1.7584 0 2.376 1,065 02/06/2016 0.002 0.573 1.8004 0 2.371 1,097 02/07/2016 0.002 0.677 1.7373 0 2.412 1,079 02/08/2016 0.003 0.616 1.7019 0 2.315 1,116 02/09/2016 0.014 0.74 1.6995 0 2.425 1,094 02/10/2016 0.009 0.652 1.6864 0 2.329 1,108 02/11/2016 0 0.817 1.6903 0 2.507 1,100 02/12/2016 0.013 0.686 1.6623 0 2.335 1,101 02/13/2016 0.003 0.595 1.6448 01 2.237 1,090 02/14/2016 0.004 0.748 1.6395 01 2.384 1,026 02/15/2016 0.003 0.862 1.6456 0 2.504 1,069 02/16/2016 0.045 0.79 1.6464 0 2.392 1,067 02/17/2016 0.023 0.768 1.6666 0 2.412 1,081 02/18/2016 0.009 0.764 1.6498 0.0268 2.431 1,072 02/19/2016 0.015 0.738 1.6548 0.0244 2.402 1,116 02/20/2016 0.001 0.544 1.6648 0.0067 2.215 1,003 02/21/2016 0.001 0.106 1.6803 0 1.785 862 02/22/2016 0.075 0.917 1.639 0.0435 2.524 887 02/23/2016 0.013 0.311 1.6199 0.0015 1.919 829 02/24/2016 0.06 0.668 1.6189 0 2.227 893 02/25/2016 0.087 0.674 1.6055 0 2.193 1,045 02/26/2016 0.015 0.673 1.6034 0 2.262 1,038 02/27/2016 0.004 0.589 1.6141 0 2.199 1,045 02/28/2016 0.014 0.687 1.6304 0 2.303 1,044 02/29/2016 0.022 0.752 1.6326 0.0432 2.405 1,039 03/01/2016 0.021 0.67 1.6356 0 2.285 1057 03/02/2016 0.019 0.545 1.6226 0 2.149 1,046 03/03/2016 0.026 0.728 1.6194 0 2.322 1,062 03/04/2016 0.004 0.592 1.6338 0 2.222 1,064 03/05/2016 0.002 0.702 1.6415 0.0104 2.352 1,067 03/06/2016 0.005 0.03 1.6651 0.0561 1.747 1,058 03/07/2016 0.006 0.471 1.6514 0 2.117 1,039 03/08/2016 0.017 0.57 1.627 0 2.18 1,053 03/09/2016 0 0.542 1.6405 0 2.182 1,061 03/10/2016 0.003 0.664 1.649 0 2.31 1,062 03/11/2016 0.048 0.569 1.637 01 2.159 1,048 03/12/2016 0.004 0.5671 1.6593 0 2.222 1,048 03/13/2016 0.017 0.4681 1.5919 0 2.043 1,048 03/14/2016 0 0.348 1.6662 0 2.014 1.066 03/15/2016 0 0.453 1.7104 0 2.163 1 MI 03/16/2016 0.315 0.584 1.7683 0.1222 2.159 1,083 03/17/2016 0 0.165 1.7563 0 1.921 961 03/18/2016 0 0.039 1.7746 01 1.814 1,018 03/19/2016 0.001 0.033 1.7649 0 1.797 1,028 03/20/2016 0.004 0.612 1.7483 0 2.357 1,028 03/21/2016 0 0.3211 1.75 0 2.071 1,056 03/22/2016 0 0.697 1.7336 0 2.431 1,052 03/23/2016 0.001 0.632 1.733 0 2.364 1,080 03/24/2016 0 0.721 1.7025 0 2.423 999 03/25/2016 0.038 0.561 1.694 0 2.218 1068 03/26/2016 0.047 0.802 1.6814 0 2.436 1,047 03/27/2016 0 0.394 1.7039 0 2.098 1,070 03/28/2016 0 0.643 1.723 0 2.366 1,059 03/29/2016 0 0.071 1.7802 0 1.851 1,054 03/30/2016 0 0.333 1.7859 0 2.119 1,052 03/31/2016 0 0.118 1.7849 0 1.903 1057 04/01/2016 0.001 0.388 1.7779 0 2.165 1059 04/02/2016 0.009 0.116 1.7277 0 1.835 1,067 04/03/2016 0.011 0.432 1.7106 0 2.131 1,044 04/04/2016 0.012 0.002 1.6962 0 1.687 1,058 04/05/2016 0.053 0.251 1.6837 0 1.883 1,024 04/06/2016 0.099 0.563 1.6799 0.0003 2.144 1,056 04/07/2016 0.086 0.406 1.671 0 1.991 1,035 04/08/2016 0.049 0.597 1.6425 0 2.19 1,030 04/09/2016 0.077 0.648 1.6383 0 2.209 1,046 04/10/2016 0.072 0.601 1.6364 0 2.166 1,046 04/11/2016 0.1 0.712 1.6437 0 2.256 1.039 04/12/2016 0.101 0.637 1.6422 0 2.178 1,041 04/13/2016 0.065 0.761 1.643 0 2.338 1042 04/14/2016 0.062 0.606 1.6406 0 2.185 1,046 04/15/2016 0.06 0.686 1.6947 0 2.321 1021 04/16/2016 0.083 0.591 1.7003 0.0001 2.208 1,043 04/17/2016 0.106 0.679 1.6731 0 2.246 1,043 04/18/2016 0.089 0.598 1.718 0 2.227 1,034 04/19/2016 0.102 0.758 1.7092 0 2.366 1,010 04/20/2016 0.098 0.588 1.6426 0 2.133 937 04/21/2016 0.106 0.813 1.7068 0 2.414 940 04/22/2016 0.111 0.759 1.6762 Ol 2.325 1,188 04/23/2016 0.05 0.7311 1.643 0 2.324 1,022 04/24/2016 0.008 0.646 1.6411 0 2.28 1,044 04/25/2016 0.141 0.884 1.6211 0.0112 2.375 1,048 04/26/2016 0.094 0.732 1.593 0 2.231 1,042 04/27/2016 0.014 0.749 1.6418 0 2.377 1,046 04/28/2016 0.019 0.635 1.6121 0 2.229 1,041 04/29/2016 0.069 0.751 1.5807 0.0697 2.332 1,039 04/30/2016 0.082 0.711 1.5941 0 2.222 1033 05/01/2016 0.069 0.874 1.5988 0 2.403 989 05/02/2016 0.099 0.721 1.5942 0 2.217 1032 05/03/2016 0.089 0.789 1.5956 0 2.296 1,010 05/04/2016 0.108 0.716 1.5965 0 2.204 1,028 05/05/2016 0.098 0.911 1.6123 0 2.425 1,009 05/06/2016 0.076 1.061 1.6121 0.0122 2.609 850 05/07/2016 0.085 1.562 1.6068 0 3.084 780 05/08/2016 0.18 0.487 1.621 0.2964 2.225 816 05/09/2016 0.115 0.933 1.6172 0 2.435 1.108 05/10/2016 0.105 0.701 1.5988 0 2.195 1.106 05/11 /20 16 0.06 1.056 1.5818 0 2.578 1,057 05/12/2016 0.046 0.734 1.5807 0 2.269 1,072 05/13/2016 0.056 1.092 1.5838 0.0001 2.62 983 05/14/2016 0.028 0.7421 1.5865 0 2.3 1,061 05/15/2016 0.096 1.009 1.6028 0 2.516 1038 05/16/2016 0.096 0.722 1.6056 0 2.231 1069 05/17/2016 0.089 0.956 1.6035 0 2.47 1037 05/18/2016 0.089 0.852 1.6004 0.0626 2.425 1066 05/19/2016 0.079 0.88 1.5844 0 2.386 1.036 05/20/2016 0.095 0.843 1.5902 0 2.337 1,059 05/21/2016 0.104 1.044 1.5767 0 2.517 1.033 05/22/2016 0.075 0.764 1.5752 0 2.264 1.058 05/23/2016 0.107 0.967 1.5784 0 2.438 1.034 05/24/2016 0.108 0.758 1.5744 0 2.224 1,057 05/25/2016 0.081 0.9381 1.5773 0 2.435 1,036 05/26/2016 0.105 0.769 1.5784 0 2.243 1,054 05/27/2016 0.1 0.826 1.5835 0 2.309 1040 05/28/2016 0.101 0.747 1.587 0 2.233 1,054 05/29/2016 0.093 0.966 1.5747 0 2.448 1,024 05/30/2016 0.1 0.769 1.5685 0 2.238 1058 05/31/2016 0.076 0.854 1.5589 0 2.337 1,041 06/01/2016 0.079 0.778 1.5619 0 2.261 1,044 06/02/2016 0.296 0.917 1.6053 0 2.226 964 06/03/2016 0.077 1.086 1.5655 0 2.575 1,027 06/04/2016 0.044 1.175 1.5564 0 2.687 1,024 06/05/2016 0.006 1.061 1.5593 0 2.614 1,038 06/06/2016 0.158 0.82 1.593 0 2.255 1,006 06/07/2016 0.391 1.192 1.6287 O 2.429 1034 06/08/2016 0.259 1.231 1.6109 ')1 2.583 1010 06/09/2016 0.005 1.442 1.5716 0 3.008 1054 06/10/2016 0.06 1.3361 1.5808 ()1 2.857 976 06/11/2016 0.077 1.266 1.5443 0 2.734 1,020 06/12/2016 0.049 1.808 1.5305 0 3.289 1,008 06/13/2016 0.037 1.468 1.5348 0 2.966 1,021 06/14/2016 0.066 1.464 1.57 0 2.969 989 06/15/2016 0.052 1.228 1.5577 0 2.734 1,012 06/16/2016 0.067 1.501 1.5828 0.0003 3.017 1,005 06/17/2016 0.065 1.4751 1.5764 0 2.9871 931 06/18/2016 0.054 2.028 1.5481 0.0002 3.522 1,019 06/19/2016 0.084 1.527 1.5796 0 3.022 1,045 06/20/2016 0.068 0.253 1.5751 0 1.759 1,087 06/21/2016 0.016 0 1.5939 0 1.578 1,115 06/22/2016 0.061 0.568 1.6031 0 2.11 1,084 06/23/2016 0.075 0.429 1.5815 0 1.935 1,125 06/24/2016 0.057 1.671 1.5393 0 3.153 838 06/25/2016 0.046 2.331 1.5588 0 3.843 488 06/26/2016 0.062 2.0211 1.567 0.0004 3.526 599 06/27/2016 0.053 1.6321 1.5518 0 3.131 775 06/28/2016 0.015 2.5551 1.5141 0.0003 4.054 956 06/29/2016 0.078 1.146 1.564 0 2.632 1,000 06/30/2016 0.076 1.539 1.5642 0.0002 3.027 985 07/01/2016 0.077 1.993 1.5539 0 3.47 982 07/02/2016 0.041 1.206 1.5346 0 2.699 981 07/03/2016 0.074 1.319 1.5293 0 2.774 979 07/04/2016 0.072 1.378 1.5531 0 2.859 981 07/05/2016 0.189 1.375 1.5582 0.0746 2.82 1,233 07/06/2016 0.192 2.3511 1.5535 0 3.712 709 07/07/2016 0.094 2.304 1.5485 0 3.759 712 07/08/2016 0.082 2.877 1.5595 0 4.355 741 07/09/2016 0.128 2.464 1.5346 0.0023 3.873 982 07/10/2016 0.105 1.633 1.5134 0 3.042 958 07/11/2016 0.087 1.084 1.523 0.0019 2.522 1,344 07/12/2016 0.083 1.672 1.5017 0.0026 3.093 1,110 07/13/2016 0.08 1.944 1.4921 0.0034 3.36 972 07/14/2016 0.043 2.986 1.4768 0.002 4.422 986 07/15/2016 0.033 2.63 1.4863 0.0004 4.083 977 07/16/2016 0.062 2.285 1.5072 0 3.73 979 07/17/2016 0.098 1.771 1.5222 0 3.195 1,008 07/18/2016 0.092 1.025 1.5447 0.0002 2.478 970 07/19/2016 0.083 0.746 1.5648 0.0005 2.229 974 07/20/2016 0.051 1.145 1.5514 0.0011 2.646 960 07/21/2016 0.071 0.738 1.5387 0.0006 2.206 991 07/22/2016 0.109 0.982 1.5542 0 2.427 982 07/23/2016 0.136 0.571 1.5571 0 1.992 969 07/24/2016 0.158 0.373 1.555 0 1.771 1,117 07/25/2016 0.071 0.387 1.5436 0 1.859 1,067 07/26/2016 0.065 0.914 1.5313 0 2.38 1,016 07/27/2016 0.028 1.195 1.4947 0 2.661 1,042 07/28/2016 0.036 1.306 1.5165 0 2.787 959 07/29/2016 0.021 1.064 1.53 0 2.573 996 07/30/2016 0.026 1.204 1.5142 0 2.692 1,000 07/31/2016 0.012 1.197 1.516 0 2.7 1,019 08/01/2016 0.104 1.235 1.4873 0.0705 HO 2.689 949 08/02/2016 0.019 1.153 1.5239 0 2.658 1,001 08/03/2016 0.054 1.076 1.549 0 2.572 1,001 08/04/2016 0.075 1.071 1.5506 0 2.547 734 08/05/2016 0.086 1.147 1.5519 2.6131 1,188 08/06/2016 0.081 1.032 1.5297 0 2.481 1,015 08/07/2016 0.069 1.231 1.5169 0 2.678 1,004 08/08/2016 0.068 1.189 1.5191 0 2.64 1,003 08/09/2016 0.03 1.162 1.526 0 2.657 1,002 08/10/2016 0.063 1.055 1.5395 0 2.532 1,000 08/11/2016 0.087 1.197 1.5506 0 2.66 994 08/12/2016 0.079 0.931 1.5417 0 2.3941 1,003 08/13/2016 0.059 1.107 1.54031 0 2.588 992 08/14/2016 0.08 0.939 1.5272 0.3707 2.756 1,003 08/15/2016 0.028 1.132 1.5905 0 2.695 975 08/16/2016 0.014 0.929 1.5805 0 2.496 997 08/17/2016 0.003 1.156 1.5657 0 2.719 974 08/18/2016 0.001 1.07 1.581 0 2.651 988 08/19/2016 0.051 1.218 1.5726 0 2.739 957 08/20/2016 0.052 1.039 1.5721 0 2.56 1,007 08/21/2016 0.077 1.405 1.5681 0.0002 2.897 971 08/22/2016 0.065 1.022 1.5762 0 2.533 988 08/23/2016 0.072 1.099 1.5824 0 2.609 977 08/24/2016 0.072 1.009 1.565 0 2.502 987 08/25/2016 0.044 1.269 1.5732 0 2.797 925 08/26/2016 0.059 0.847 1.5908 0 2.378 976 08/27/2016 0.062 1.068 1.5979 0 2.604 960 08/28/2016 0.033 0.764 1.614 0 2.345 948 08/29/2016 0.065 0.917 1.658 0 2.51 985 08/30/2016 0.05 0.853 1.6345 0 2.438 987 08/31/2016 0.023 0.937 1.6242 0 2.539 983 09/01/2016 0.063 0.814 1.6307 0 2.381 991 09/02/2016 0.018 0.945 1.6328 0 2.56 986 09/03/2016 0.021 0.812 1.6269 0 2.417 986 09/04/2016 0.022 0.871 1.6101 0 2.459 917 09/05/2016 0.037 0.752 1.623 0 2.338 951 09/06/2016 0.02 0.946 1.6365 0 2.562 955 09/07/2016 0.02 0.726 1.6444 0 2.35 963 09/08/2016 0.009 0.841 1.6268 0 2.46 955 09/09/2016 0.002 0.749 1.6152 0 2.363 950 09/10/2016 0.037 1.006 1.6099 0 2.579 863 09/11/2016 0.029 0.727 1.6256 0 2.324 919 09/12/2016 0.092 0.854 1.6284 0 2.39 878 09/13/2016 0.091 0.736 1.6185 0 2.264 911 09/14/2016 0.055 0.985 1.6216 0 2.552 882 09/15/2016 0.035 0.846 1.6256 0 2.436 877 09/16/2016 0.02 0.947 1.6165 0 2.543 877 09/17/2016 0.005 0.742 1.5977 0 2.335 905 09/18/2016 0.113 1.232 1.618 0.0175 2.755 847 09/19/2016 0.04 0.814 1.5573 0.0315 2.362 911 09/20/2016 0.021 1.041 1.5315 0 2.551 920 09/21/2016 0.038 0.8081 1.5087 0 2.279 902 09/22/2016 0.03 0.997 1.5452 0 2.512 875 09/23/2016 0.003 0.898 1.561 0 2.456 919 09/24/2016 0.005 1.017 1.5806 0 2.593 910 09/25/2016 0.013 0.902 1.5902 0 2.478 910 09/26/2016 0.001 0.928 1.6021 0.0001 2.529 900 09/27/2016 0.012 1.318 1.6117 0.0001 2.917 892 09/28/2016 0.0121 1.13 1.595 0.0003 2.714 914 09/29/2016 0.005 0.755 1.5824 0 2.332 914 09/30/2016 1 0.021 0.7721 1.5783 0 2.33 930 10/01/2016 0.214 0.663 1.5774 0.0858 2.112 884 10/02/2016 0.048 0.918 1.5856 0.019 2.475 874 10/03/2016 0.029 0.988 1.6911 0.019 2.669 902 10/04/2016 0.001 0.744 1.6152 0.1362 2.494 900 10/05/2016 0.028 0.262 1.6007 0.1769 2.011 901 10/06/2016 0.1 0.625 1.6173 0.0627 2.205 844 10/07/2016 0.138 0.8361 1.6164 01 2.315 868 10/08/2016 0.102 0.957 1.5981 0 2.453 882 10/09/2016 0.096 0.57 1.5934 0 2.067 886 10/10/2016 0.07 0.858 1.634 0.0004 2.423 875 10/11/2016 0.081 0.506 1.6208 0.0004 2.046 883 10/12/2016 0.094 0.871 1.6093 0 2.387 878 10/13/2016 0.095 0.722 1.6078 0.0001 2.235 878 10/14/2016 0.09 0.83 1.6121 0.0005 2.353 899 10/15/2016 0.034 0.763 1.5787 0.0104 2.318 889 10/16/2016 0.058 0.769 1.619 0.0025 2.332 878 10/17/2016 0.024 0.718 1.6418 0.0002 2.336 884 10/18/2016 0.003 0.792 1.6433 0.0007 2.433 811 10/19/2016 0.019 0.7 1.6644 0.0006 2.346 753 10/20/2016 0.005 0.869 1.6524 0.0019 2.518 851 10/21/2016 0.005 0.722 1.6243 0 2.341 843 10/22/2016 0.015 0.788 1.6238 0.0002 2.397 1,038 10/23/2016 0.002 0.74 1.6236 0 2.362 904 10/24/2016 0.008 0.752 1.677 0 2.422 889 10/25/2016 0.022 0.674 1.6398 0 2.291 893 10/26/2016 0.006 0.703 1.624 0 2.321 893 10/27/2016 0.029 0.578 1.6307 0 2.18 857 10/28/2016 0.008 0.6211 1.6648 0.0005 2.278 872 10/29/2016 0.053 0.5791 1.6282 0 2.154 884 10/30/2016 0.138 0.752 1.6127 0.0171 2.244 876 10/31/2016 0.021 0.644 1.6242 0.0002 2.248 891 11/01/2016 0.004 0.64 1.6542 0 2.29 872 11/02/2016 0.036 0 1.6278 0 1.592 888 11/03/2016 0.01 0.481 1.6406 0 2.111 868 11/04/2016 0.005 0.587 1.6427 0 2.225 884 11/05/2016 0.017 0.838 1.6649 0 2.486 877 11/06/2016 0 0.572 1.7288 0.0009 2.302 936 11/07/2016 0.002 0.722 1.6719 0.0009 2.392 876 11/08/2016 0.004 0.557 1.6419 0.0009 2.196 885 11/09/2016 0.004 0.616 1.6401 0 2.252 857 11/10/2016 0.021 0.548 1.6516 0 2.178 874 11/11/2016 0.026 0.472 1.6343 0.0017 2.081 858 11/12/2016 0 0.003 1.6338 0 1.637 870 11/13/2016 0.025 0.155 1.6339 0 1.764 876 11/14/2016 0.036 0.501 1.607 0.0002 2.073 634 11/15/2016 0.008 0.353 1.6584 0.001 2.005 1,028 11/16/2016 0.001 0.479 1.6878 0.0014 2.167 979 11/17/2016 0.004 0.371 1.6631 0 2.029 852 11/18/2016 0.002 0 1.6604 0 1.658 1,226 11/19/2016 0 0.421 1.6366 0 2.057 1,017 11/20/2016 0 0.482 1.6865 0 2.168 1,015 11/21/2016 0 0.849 1.6729 0.0003 2.521 1,033 11/22/2016 0.042 0.483 1.663 0.2138 2.318 1,013 11/23/2016 0.029 0.418 1.686 2i 2.075 991 11/24/2016 0 0 1.683 0 1.6831 1,049 11/25/2016 0 0.24 1.6965 01 1.9361 970 11/26/2016 0 0 1.6905 0 1.69 1,039 11/27/2016 0.004 0.314 1.6918 0 2.002 995 11/28/2016 0 0 1.6992 0 1.699 1,020 11/29/2016 0.005 0.222 1.728 0 1.945 980 11/30/2016 0 0 1.7438 0 1.744 1,005 12/01/2016 0.011 0.155 1.7414 0 1.885 997 12/02/2016 0 0.039 1.7184 01 1.757 1,004 12/03/2016 0 0.205 1.7476 0 1.952 981 12/04/2016 0 0 1.7651 0 1.765 984 12/05/2016 0 0.12 1.7695 0 1.889 965 12/06/2016 0 0 1.7729 0 1.773 979 12/07/2016 0 0.044 1.779 0 1.823 967 12/08/2016 0 0 1.7813 0 1.781 967 12/09/2016 0.001 0.096 1.7713 0 1.866 985 12/10/2016 0 01 1.729 0 1.729 975 12/11/2016 0.001 0.033 1.7255 0 1.758 957 12/12/2016 0 0 1.7112 0 1.711 977 12/13/2016 0.025 0.073 1.6986 0 1.747 896 12/14/2016 0.016 0 1.7264 0 1.711 921 12/15/2016 0.007 0.255 1.7206 0 1.969 949 12/16/2016 0.032 0 1.6567 0 1.625 951 12/17/2016 0.051 0.143 1.6562 0.0005 1.748 930 12/18/2016 0.035 0 1.6772 0.001 1.643 959 12/19/2016 0.005 0.323 1.6699 0 1.988 941 12/20/2016 0 0 1.697 0 1.697 948 12/21/2016 0 0.101 1.6906 0 1.792 939 12/22/2016 0 0 1.7058 0 1.706 942 12/23/2016 0.029 0.141 1.7084 0 1.82 932 12/24/2016 0 0 1.7232 0 1.723 940 12/25/2016 0.001 0.189 1.6853 0 1.873 937 12/26/2016 0.003 0 1.717 0 1.714 938 12/27/2016 0.001 0.196 1.7323 0 1.927 921 12/28/2016 0 0 1.7567 0 1.757 935 12/29/2016 0.023 0.171 1.7423 0 1.89 928 12/30/2016 0.028 0 1.6774 ()1 1.649 934 12/31/2016 0.0111 0.254 1.6615 ()1 1.904 890 ~4 ) ) ,(1ù'·,"',l", ", IF'', :" ' ¡/,iII.'\" ",,~U'.,·:JI ' "J,r," .\,,":, 1",: ".'\' ',i :1 F' I,. '~. ,: {.¡,j, : ,! 'I; \: .' } ~ '\ ' ",\, æ)ULlu':.~ r~u ¡Iii .¡:::1 ~I ¡ :,\ j, :~ \"~ u tn, P ¡' ;'1~' r?l:j " t\, ') 'ii ' Ï' \ \, J .! ',) \ J"¡ i ! 'II '\ '''·<>ì'-, I :::. '\ 'I 'il i::;:\, ·~'ì .(" '\ ':, 'I I" ,1,1, ':-1 ] ¡ ::,,,.;1 ~:t...=J LJ :ì..J':~':':./ IT\ l l \1.\ / iJ\ /Fd FRANK H. MURKOWSKI, GOVERNOR A I,.SIi& OIL AlID GAS CONSERVATION COMJIISSION 333 W. 7fH 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 correcti ve 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.i ection 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 Operating 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 AlO 11 - Granite Point 5 6 8 Field; Southern Portion AlO 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 AID 16 - Kuparuk River 6 7 10 Unit; Tam Oil Pool 6 8 AID 1 7 Badami Unit 5 AID 18A·- Colville River 6 7 11 Unit; Alpine Oil Pool AID 19 - Duck Island Unit; 5 6 9 Eider Oil Pool AID 20 - Prudhoe Bay Unit; 5 6 9 Midnight Sun Oil Pool AID 21 - Kuparuk River 4 No rule 6 Unit; Meltwater Oil Pool AID 22C - Prudhoe Bay 5 No rule 8 Unit; Aurora Oil Pool 6 9 AID 23 Northstar Unit 5 AID 24 - Prudhoe Bay Unit; 5 No rule 9 Borealis Oil Pool AID 25 - Prudhoe Bay Unit; 6 8 13 Polaris Oil Pool AID 26 - Prudhoe Bay Unit; 6 No rule 13 Orion Oil Pool I I Disposal Injection Orders DIG 1 - Kenai Unit; KU No rule No rule No rule WD-l DID 2 - Kenai Unit; KU 14- No rule No rule No rule 4 DIG 3 - Beluga River Gas No rule No rule No rule Field; BR WD-l DIG 4 - Beaver Creek Unit; No rule No rule No rule BC-2 DIG 5 - Barrow Gas Field; No rule No rule No rule South Barrow #5 DIG 6 - Lewis River Gas No rule No rule 3 Field; WD-l DIG 7 - West McArthur 2 3 5 River Unit; WMRU D-l DIG 8 - Beaver Creek Unit; 2 3 5 BC-3 DID 9 - Kenai Unit; KU 11- 2 3 4 17 D 10 10 - Granite Point 2 3 l 5 ! Field; GP 44-11 Affected Rules "Demonstration of "Well Integrity "Administrati ve Injection Order Mechanical Failure and Action" Integrity" Confinement" DIO II - 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; NCill A-12 DIG 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 DI 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 K.Fl Storage 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.i ection Orders EIO 1 - Prudhoe Bay Unit; No rule 8 Prudhoe Bay Field, Schrader No rule Bluff Fonnation Well V-I OS ) ) Affected Rules Injection Order "Demonstration of "Well Integrity "Administrati ve Mechanical Failure and Action" Integrity" Confinement" EIO 2 - Redoubt Unit; RU-6 5 8 9 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM STATE OF ALASKA ADVERTISING ORDER ~EFBO'TTOM..f1iºB.'NYº'CEADI)~g~$ NOTICE TO PUBLISHER ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AO-0251401. 6 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATIACHED COPY OF ADVERTISEMENT MUST BE SUBMITIED WITH INVOICE F AOGCC 333 West th Avenue, Suite 100 Au1chorage,AK 99501 907-793-1221 AGENCY CONTACT DATE OF A.O. R o M Jodv r. · PHONE (907) 791 -1 )) 1 DATES ADVERTISEMENT REQVIRED: . . C"' II; In ')7 )004 PCI\J 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 INSTRVCTJONS: 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 To: undisclosed~recipients:; BÇC: Cynthia BMcLver<bren_mciver@admin.state.ak:.1,1s>, AngelaWebb . <angie~webb@adniil);.state.ak.us>,· RobertE Mintz. <rob~rt ~l111~~@lil\".statè.ak~us>, Chri~tine . Hansen <c.hansen@iogcc..state.ok.us> ,·Terrie Hubble <hubþletl@bp.com.>, Sondra Stewman <Stewma:SD@BP.co.m>,. Scott & Cammy TayI~r <staylor@~láska'llet>, ~tanekJ <stanekj@Unocal.com>, ecolaw <ecolaw@trùstees.org>, roseragsdale <ro~erag~dale@gci.net>, tnnjr1 <tnnjrl @aol.corrt> ,. jbridd1e. <jbriddle@marath0llOil.com>, rockhilI <rockhill@aoga.org>, shaneg <shan~g@evergre.engas.com>, jdarlington <jdarlìngton@f~rest.oi1.coµt>,.~n~lsòn: <knelson@petroleumnews~com?, cbQddy <cboddy@usibelli.co$>,Mark Dalton· .' <mark.da~toti@hdiiÎ1c.com>, Shannon . Donnelly <Shannoii.donneUy@conocophillips.coni>~. '~~ark P. W9rcestei" <mark.p.worcester@coriQcophil1îps~com>, "JerryC. Dethlefs"· .'..~ .. <jerry .c.dethlefs@con~cöphil1ips.com>, ·.Bob <bob@inletkeeper.org>, wdv <wdv@4m".statè.ak.us>, tjr <tjr@dnr.state.ak.us>, bbritch ~bþritch@alaska.net>, mjnelson <ITljnelson@purvìngerti.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Paul G. Hyatt" <hyattpg@BP.com>,"StevenR. Rossberg" <RpssbeRS@BP.com>, Lois <lois@inletkeeper.org>, D~aro$s.<kuacnews@kUac..org>, Gordon Pospisil <PospisG@BP~com>, "Francis S. SoIin1ier" <SonunerFS@BP~cöm>,Mîk.~l Schultz <MikeLSchultz@BP . com> , "NickW. Glover". <GloverN\V@BP:.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, I'Janet D. Platt" <PlattJD@BP .com>, "R.9sanneM. Jacobsen" <JacobsRM@BP;com>, ddonkel <ddonkel@cfl.lT~com>, Collins Mount <collins _ mount@revenue.state.ak.us>, mckay <mckªy@gci.net>, Barb~a F Fullmer <barbara.£fullmer@conocophillips.com>, bocastwf <bocasìwf@bp..com>,· Charles.Bark~r: . <barker@usgs.gov> , doug_schultze <doug_ schultze@xtoenergy~c.QIr1>, .Hank Alford . <hank.ålford@exxonmobil.com>,.MarkKovac <yesnril@gci.net>, gspfoff, <gspfoff@aurorapower.com>, Gregg Nady <greg~.nady@shell.com>, Fred 8teece <fred.steece@state.sd.us:>., rcrotty <rcrotty@ch2m.com>, jejones <jejones@ailrorapower.com>, dapa <dapa@alask~.net>, jroderick <JJ,"()derick@gci~n~t>, eyancy <eY~9y@seal-tite.net>, "James M. Ruud" <j ames.m.ruud@conoc()phillips.~Qm>, Br~t Lively: <mapalaSKa@ák.net>, jab <jah@dnr.state.ak.us>, Kurt E Olson <kurt~olson@legis.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, loren_ternan <loren_)emap.@gov~state.ak.us>,. Julie Houle <julie_houle@dnr.state.ak.us>, John WKatz<jwkatz@ss,o.ori>, Sl1Z~J"Hi~l . <suzan_hil1@dec.state.ak.us>, tablerk <tablerk@unoca1.com>, Brady <brady@~oga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough~kenai.ak.us>, Ji~. White <jimwhite@satx:.rr.com>, "John S. Haworth" <john.s~haworth@e.xxonmobil.com>, marty <:~~~J:~~~~~~fflir~om>, .gbammons. <gbammons@ao1.coni>~ n¢le~ <~çlr~~t1-~~~~.~~ka.net>, mkm7200 <mkm7200@aol:com>,.ßIian Gillespie <i:t1,}it1g@µ~~~}(:~~~Íl>; David L Boelens <dboele~@aurorapo~er.cOti1>, Todd DUrkee ~.~..~~~i~~1.R6~.~~i;~· <bg(lgfi9n@brê];1alaw.~~~s>~P,-,~1·"W'~~~I~w5þmA~inslow@for~s~~Lcom>, Garry· Catron': . . <q~~on~<$br'F?~>,,."Sh~aiµ~...Ç()p~l~d..<:c~p;~I~v@bp..c{)JJl>, ~·uzantie: Allex~ <s~}Y~~($h,~ItIl~~e1"~.ge~>-,IÇI.i$flhI>i~~~;:<~tin _ dirks@dnr·s~e.akUS>~.IÇ~yœll Z¢~~ >gzen1~(@~gù-~~(Ji,J.Ç~tn>,J9§t1·Tow~r .gjo~~Towei@ei~4oe.gov>,. Bijl Fowl~r ..' <Bil1_F 9Wler@anadårk(i~c.Ol\rf> ,Va.ugñnS""åÎtz<vaughn.swartz@rbccm.com>, Scott Çrªºswî¢~· 10f2 9/29/2004 1: 10 PM Public Notices <scottcranswick@mms.gov>, Brad McKim <mckimbs@B]?com> tLea.se.find the attGiched Notice and Attachméntfor tb.~. proR~sed amendment of underg:çotlnd injectioriorders and the Public Notice HappyVa:iley #10. Jbdy Cblombie . r - ¡ çônt~nt-Typ~: åppIication/11lsword Mechanical Integrity ofWensNotice~doc·¡.. i ... ..... ....................... ... ···b· ·6.4.·· ;Content~EnC9d.lng: . .. ase ¡ Content-Type: appTication/msword HappyVal.leyl 0 _lIearingNotice.doc .. Content..Encpding: base64 .... """ "'..._. ",'.w,__., .;..,,~..,..___..,". '~._:":-'~-:.W"'~""""",' """_M' ."__",.._." ',' ''''~''.'' ....."".... _. _."' _·",'w.."".,... ".._ ":'"."._ ..."..'.....-......,..7........-. ._'..'~M'...__W.... ,.-:...;..-"~".".."... .~~_____ ~,__...._._.;,."__.._._.,,__,_..,, ','" ~,__"..." ......, ".._ .....;.._,......~., 20f2 9/29/2004 1: 10 PM Public Notice Subject: Public Notice From: Jody Colombie <jody _ colombie@admin.state.ak.us> Date: Wed, 29 Sep 2004 -0800 To: legal@alaskajournal.com Please publish the attached Notice on October 3, 2004. Thank you. Jody Colombie Content-Type: applicationlmsword Mechanical Integrity of Wells Notice.doc Content-Encoding: base64 Content-Type: applicationlmsword Ad Order form.doc Content-Encoding: base64 I of 1 9/29/2004 1: 10 PM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 /,1tZ¡l¿d /(//(()'~ David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 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 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 John Levorsen 200 North 3rd Street. #1202 Boise,lD 83702 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Baker Oíl Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 James Gibbs PO Box 1597 Soldotna, AK 99669 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Cliff Burglin PO Box 70131 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 North Slope Borough PO Box 69 Barrow, AK 99723 .. [Fwd: Re: Consistent Wording for Injection ~rs - Well Integrity... ) ~ubject:,'[Fwd: ·Re: . G()l1sistentW örgirl~..,~ºt IrlJ~cti()n .,Ofd~ts··-WêHlQt¢g:tir~rÇR~vis~d)J From: JOM Norman,<john.,.norman@ädmin~state~ak.u~> '.,....,"..,'."..':.'~, .,'..,..',....,..", ,"".."".,,',., "";.". Dâte:Fri, 01 Oct 200411:09:26;;.0800 To.: Jody J Colombie <jody_colombie@admin.state.ak.us> 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 <[obert mintz~law.state.ak.us> To:jim regg;(â}admin.state.ak.us CC:dan seamount(C4admin.state.ak.us, john nonnan(C4admin.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 <¡im 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 <¡iill 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 lody 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 10f2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injection èrs - \Vell 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", "USDWs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg JohnK. 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 )rs - Well Integrity... ) Subject: [Fwd: Re:ConsistentW ording. for Injection Orders ~ Well Ihtégrity(Revìs¢cl)] ~r()ll1: John Nonnan <jooo_nonnan@admírr.state.a1(.µs> Date: Fri, 01 Oct 2004 11 :08:55 -0800 To: Jody J Colombie <jody_colombie@admin.state.ak.us> 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 2004 15:46:31 -0800 From:Rob Mintz <robert mintz(ã¿law.state.ak.us> To:dan seamount(ã¿admin.state.ak.us, jim regg~admin.state.ak.us, john nOffilan~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 redlines 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 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 10f2 10/2/20044:07 PM [Fwd: Re: Consistent Wording for Injection ~rs - Well Integrity ... - adopts "Administrative Actions" title (earlier rules used "Administrative RelieC'); - 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", "USDWs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg ; John K.Nonnan <John Norman~admin.state.us> : Commissioner : Alaska Oil & Gas Cmservation Commission , Content-Type: applicationJmsword Injection Order language - questions.doc Content-Encoding: base64 Content-Type: applicationlmsword Injection Orders language edits. doc Content-Encoding: base64 20f2 10/2/20044:07 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 Integritv 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 F onn 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 every two veal'S in the case of a slurry iniection well), and before returning a wen to service folloyving afte.t: a workover affecting mechanical integrity~ and o.t least once e'.'ery /1 year:; while acti':ely injecting. For ~;!""lrry -iE:jt~lls, th~ tubing/casing aI'J1ulus ¡nust b~ tèsted [(:")1" mechJ.nical integrity èvery 2 years. Unless an alternate 111eans is approved bv the COlnnlission. Inechanical integrity Inust be delTIOnstratcd bv a tubing pressure test using a =Rte Mt+-surface pressure OfOlust be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, that ffl-HSt-show;i stabilizing pressure that doesand Inay not change more than 1 O~ percent during a 30 minute period. ~ alten1ate nleJ.ilJ of dernøn~trQtin; lTIech:'-'..nical integrity rnust be appro'/Exl by the COlnnlis~ion. The Commission must be notitìed 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, +!he tubing, casing and packer of an injection well must tk~lnaintain integrity during operation. \Vhenever any pressure conlffiunication, leakage or lack of iniection zone isolation is indicated bv injection rate. operating pressure observation, test survev, log. or other evidencc, t+he operator fH:H5t-shaIl immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval.:. ~r any prössure C01TIlTIUnlUltlOn, leakage or lack of injection zone isolation is indi~ated by injection ratc. opcrating pressure obscr\"atíon, te~;t, sur/ey. or log. The operator shall shut in the well if so directed bv the C0I1J111ission. Thc operator shall shut in the \-veIl without a\vaiting a response from the COffilnission if continued operation \vould be unsafe or would threaten contamination of freshwaterIf ther~ is no threat to freshv;ater, injection tnay continue until the COlTIlnission require:=: the ',\"e11 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. p[Fwd: Re: [Fwd: AOGCC Proposed WI Lanh ]e for Injectors]] ) StllJ,Ject: [Fwd: Re: [Fwd: AOGCC Proposed WI Language for Irtjectòrs]] fr~m:..Wifiton·.Aubert ·<wint()n_aubert@adrnin.state.ak:;us> º~'~~:1?P,llt~~qctfOp4g9:4&:?3~O~.qO, . ...:. ..".....'., .... ....'. . r~;·...'~~ªY:~..ç~~î(:J~~~Ë:'·..51,q;~¥t~ÖJQt#1:)~¢~ªq~w.~'~~~~~;~~~~?,.......... ,.".,., 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 <jirn regg@admin.state.ak.us> Organization: State of Alaska To: Winton Aubert <winton aubert@admin.state.ak.us> References: <41812422.8080604@adrnin.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 <EngeIHR@BP.com> winton aubert@adrnin.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* ** 10f3 10/28/2004 11:09 AM [Fwd: Re: [Fwd: AOGCC Proposed WI Lanh :: for Injectors]] returnj.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 witnessed MITIA 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 requirement.s are clear r but it I 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 A¡ Digert, Scott A; Denis, John R (ANC); Miller, Mike E¡ 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 of3 10/28/2004 11 :09 AM #3 • • S,tx .jk f ~~:~~%1~':s`~1 ~:~ ~~:;~iC~i BP EXPLORATION April 15, 1999 Robert N. Christenson, Chairman Alaska Oil and Gas Conservation Commission. 3001 Porcupine Drive Anchorage, AK 99501 b >-~~: SR F Arc.4c_., SP s~ SYr=_' ; ~~C;rs E 57, z_,..,..ie~°,~f F Dear Mr. Christenson, Re: Area Injection Order No. 17: Injection of Kekiktuk Gas into the Badami Reservoir The side-track of the 81-36 development/exploration well is currently underway. Upon its successful completion, we plan to begin a production test of the Kekiktuk formation. BPX as Badami operator, seeks Commission concurrence for the injection of gas from the Kekiktuk Formation into the Badami reservoir. Please advise us if there is anything we need to do, before injection of the Kekiktuk gas commences, to comply with your regulatory requirements. The well is expected to be completed, tied in to the facilities, and available for testing from the Kekiktuk interval by the middle of May. Sincerely, /, /~ i J'~' // (.~ tip` Gary Osborne Eastern North Slope Subsurface Manager cc: B.Turnbull ]. Dukes File: AOGCC APR 22 '99 04~04PM BPX ENDICOTT DEVP .+ r . B~'Amoco P.1i2 Fax Message BP exploration (Alaska) Inc, P.O. Box 196612 MB3-6 900 E. Benson Boulevard Anchorage Alaska 99519-6612 Switchboard: (907) 561-5111 Central Fax: (907) 564.5200 Date; ~ ~'~~..,/ ~ °~ Team: P ~N ~ Direct Fax: (907) 564-5200 Subject ~~ ~ Pl ~ nth ~ Direct Tel: (807) 564- v r _ :J ~ Pages to follow: URGENT ORDINARY CONFIDENTIAL n Company; Copy to; Teem: Fax no: ~~ ~ ~ ~ "~ ~ j ~ Message; d~o~.a ~ co~~ ,R ~_„dQ -V '~~kJ APR 22,.`'99 04~05PM BPX ENDICOTT DEVP '' 1`urnbull, Bill F From: Turnbull, Bill F Sent: To: Thursday, Appril 22, 1999 2:46 PM 'bob crandall~admin stat k ' Cc: . e.a .us Osborne, Gary M.; Angert, Patrick FA (ANC) Subject: Badami Bubble point and API data Bob, Here Is the Badami data you requested Well Bubble Point Oil Gravity from PVT (pSi) - (API) Badami 1 -------- 3340 -------Za------- eadaml2 2780 19 Badami S 3098 25 Well OII Gravity ---- (API) ----- B1-11A 24 --------- 81-14 28-30 81-15 25-Z7 81-l6 ~ Bl-18 30 61-21 26-29 Bl-25 z7 BS-28 21-22 The attached excel file contains also contains Chis data. ~~ KtC1d ~ 8edeni bunnn pemt And oq grouib.xle \J P.2i2 I can confirm mat I have passed your interest in the Bt-36 Kekiktuk logs on to the exploration geologist looking after the well. Thanks, Bill Turnbull Eastern North Slope PE 564-4662 turnbuwf@bp.com Page 1 #2 ) ) ) ') BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 1, 1998 Mr. David W. Johnston, Chairman State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Badami Area Injection Qrder . I,..... . !i'''''it·::':.':Ti' Dear Mr. Johnston: Further to our meeting of March 23,1998 and pursuant to 20 AAC 25.402 and 20 AAC 25.460 BP Exploration (Alaska) Inc. (BPXA), as Badami Unit Operator, respectfully submits on behalf of the Badami Working Interest Owners an application for the Badami Area Injection Order. Should you need any additional information to support this application, please contact me at 564-5789. Sincerely, /~~ w. L. Bredar Manager Subsurface, Badami RECEIVED r f T' I C ~ 19 o \"':iJ I 1 98 Alaska on & Gas Cons. Commission Anchorage ) ) '\ ) APPLICATION FOR BADAMI AREA INJECTION ORDER 20 AAC 25.460 20 AAC 25.402 ') ') ',\ I' ) SECTION A Application for Badami Area Injection Order 20 AAC 25.460 20 AAC 25.402 BP Exploration (Alaska) Inc. (BPXA) in its capacity as a Working Interest Owner (WIO) and the Operator of the Badami Sands Participating Area (BSP A), hereby applies for an Area Injection Order (AIO) to cover proposed water and miscible fluid injection operations. BPXA is requesting that the AIO be granted to cover operations in which BPXA will act as Operator, including the Badami pool as currently defined in Conservation Order 402 (Exhibit A-I). In association with an enhanced oil recovery (EOR) project, three types of injection fluid will be utilized in the proposed Badami injection area: . source water . produced water · miscible hydrocarbon gas. In addition to the fluids specifically associated with the EOR project, the following other incidental fluids may be injected into the Badami oil pool at some time during the project: · sea water to thermally frac gas injection wells · gray water from the waste water treatment plant · ponded and/or storm water from the pad area . solution gas associated with oil production . tracer survey fluid to monitor reservoir performance. Exhibit A-I details the area included in the proposed Badami injection area. The legal description of the area included in the Badami AIO is listed in Exhibit A-2. Badami Development Plan The Badami Phase I project will be a stand alone development, providing full process and export facilities for up to 35,000 barrel per day (bpd) oil, 22.5 million standard cubic feet per day (scfd) produced gas, 28 million scfd injection gas, 10 million scfd lift gas, 13,600 bdp produced water, and 30,000 bpd source water. Source water flood, miscible flood, and gas lift will be available soon after startup. The pipeline system consists of a 12-inch crude export line which ties in to the existing 16-inch Endicott crude export line, as well as a 6-inch ) ) ) ) utility line for providing miscible fluids from Endicott (primary source) for use in the Badami EOR project. The single, onshore pad base development includes slots for 20 production wells, 15 water/miscible fluid injection wells, plus two source water wells and one Class I waste disposal well. Drilling began in September 1997 with plans for 5-7 production wells to be completed and available by facility startup in fourth quarter 1998. Development drilling will continue through the end of 2000. Badami Phase 2 is currently defined as the remaining potential of the Badami Sands that could be accessed by drilling additional wells in the pool area. ¡) } ) ') Section B Plat 20 AAC 25.402 (c)(l) Exhibit A-I is a plat showing the location of existing and/or proposed injection wells, existing and/or proposed production wells, and the four original Badami exploration and appraisal wells. ) ') ) ') Section C Operators/Surface Owners 20 AAC 25.402 (c)(2) The surface owners and operators within a one-quarter mile radius of the Badami pool are: State of Alaska Department of Natural Resources Attn: Carol Lee P.O. Box 107034 Anchorage, AK 99510 BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ), ') } ') Section D Affidavit 20 AAC 25.402(c)(3) Exhibit D-l is an affidavit showing that the Operators and Surface Owners within a one- quarter mile radius of any proposed injection well in the Badami pool have been notified and provided a copy of the application. '), ) ) ") Section E Description of Operation 20 AAC 25.402 (c)(4) This is an injection order for the injection of Class II fluids in connection with an EOR operation. It does not include the drilling of wells for dedicated Class II disposal operations. Subsection I Enhanced Recovery Enhanced recovery injection wells are used for the introduction of additional fluids into a reservoir to increase the ultimate recovery of oil. Two types of enhanced recovery operations are planned within the proposed Badami injection area: water and miscible fluid injection. Facilities for water and miscible fluid injection should be in place by fourth quarter 1998. Well Spacin~ Nominal20-acre well spacing has been established for the Badami pool. No well bore may be open to the pool within 500 feet of the external boundary of the pool area or within 700 feet of another well capable of producing from the same pool (Conservation Order 402). Well Counts Current Phase I plans include 35 wells (20 production wells and 15 injection wells) plus two shallow water source wells. Phase 2 plans may include up to 24 additional wells. ) ) ~ ") Section F Pool Information 20 AAC 25.402(c)(5) The proposed Badami injection area includes the Badami oil pool in the Canning Formation. The Badami oil pool is defined as the accumulation of hydrocarbons common to and correlating with the interval between the measured depths of 9,500 feet and 11,500 feet in the Badami #1 well as stated in Conservation Order 402. ) ) '\ ') Section G Geologic Information 20 AAC 25.402(c)(6) Injection Interval Stratigraphy and Litholo~v The reservoir to be affected by injection is the Badami oil pool (reservoir). The Badami reservoir is contained within the Canning Formation and was deposited during the Lower Paleocene geologic time period. Exhibit G-l illustrates the stratigraphy of the Badami reservoir on the Badami # 1 type log. This log is scaled in true vertical depth from the rotary kelly bushing (TVDrkb). Measured depths are also indicated. The top of the Badami reservoir occurs at a depth of 9000 feet TVDrkb (9500 feet MD rkb). The base of the Badami reservoir occurs at a depth of 10870 TVDrkb (11500 MDrkb). The Badami reservoir is stratigraphically complex. It is characterized by rapid changes in interval thickness, lithofacies, net sand and oil quality. The Canning Formation is comprised of shale, siltstone and sandstone. The Badami reservoir contains similar lithologies with most of the sandstone occurring in the basal portions. Lateral variations in stratigraphy have been characterized and augmented with well data and 3D seismic control. Interpretations of the cores, well logs and seismic has resulted in the conclusion that the Badami reservoir was deposited as a turbidite which onlaps onto the paleoslope and downlaps onto the basin floor. Core analysis indicates that the Badami reservoir is a medium to very fine grained sandstone. The pore throats are usually equant in shape with silica overgrowths serving as the primary cementing agent. The reservoir is mineralogically mature, composed of 80% quartz, 10% lithic rock fragments and carbonaceous material and 10% clay. Structure As shown on Exhibit G-2 the structure for the Badami reservoir consists ofmonoclinal dips to the north and northeast. The trapping mechanism for the Badami reservoir is entirely stratigraphic in nature. Confining Intervals As previously mentioned, the Badami reservoir is contained within the Canning Formation of Lower Paleocene age. The Canning Formation is interpreted to be a deep water shale present throughout the entire area. The Canning shale is extremely impermeable with a thickness of approximately 500 feet above and below the Badami reservoir as illustrated in the Badami #1 type log - Exhibit G-l. ) ) ) ') The Canning shale is overlain by the West Sak Formation and underlain by the Lower Brookian aged HRZ interval throughout the entire injection area. The West Sak Formation represents the final marine regressive sequence of the Middle Brookian section of Tertiary time (Paleocene to Middle Eocene). The West Sak Formation is composed of fine to medium grained sandstones and capped by a shallow shelf and coastal plain, fluvial fine to medium grained, sandstone (Ugnu Formation). The underlying HRZ interval is a pelagic shale deposited in distal toesets throughout the Lower Brookian. It is also continuous throughout the entire area Exhibit G-3 which is a well log cross-section illustrates the stratigraphy and relative positions of the Ugnu Formation, West Sak Formation, Canning Formation, Badami reservoir and HRZ lithologic units. e e . e Section H Well Logs 20 AAC 25.402(c)(7) Copies of all open hole logs from Badami wells are sent to the Commission as the wells are completed. Exhibit G-l is the type log for the proposed Badami injection area with stratigraphic and marker horizons annotated. e e .e Section I Casing Information 20 AAC 25.402(c)(8) 20 AAC 25.252(c)(6) Current development plans for Badami include 15 injectors. Injection in all ofthe wells will be a continuous cycle of water followed by miscible hydrocarbon gas. This process is called "water alternating gas" or WAG. At this time, two of the injection wells are planned for pre- production prior to conversion to injection. Tubing size in the Badami field will be 4Yí inches. The well design is similar to Kuparuk and Prudhoe Bay fields "slimhole" wells. The design utilizes 9-5/8 inch surface casing, 7 inch intermediate casing, and 4Yí inch production liner. All Badami wells will be completed with L-80 grade steel. Most Badami water injection completions are currently envisioned as dual zone, single string with a single packer. Exhibit 1-1 shows a typical wellbore schematic for the completion design. The actual casing program is included with the "Application to Drill" for each well and is documented with the AOGCC in the completion record. API injection casing specifications are included on each drilling permit application. All injection casing is cemented and tested in accordance with 20 AAC 25.412. e e -e Section J Injection Fluid 20 AAC 25.402(c)(9) 20 AAC 25.252(c)(7) Subsection 1 Enhanced Recovery In association with the EOR project, three primary types of injection fluid will be utilized in the Badami injection area: · source water · produced water · miscible hydrocarbon gas. Source Water Source water will be obtained from the two source water wells. These wells use electric submersible pumps (ESPs) to lift the source water from the Sagavanirktok Formation. This is the same formation that is supplying source water to the Milne Point development. 1) Analvsis of Composition of Tvpical Fluid Exhibit J-l shows the chemical composition of the Sagavanirktok Formation water sample collected from the Badami #5 (also see Section M). 2) Estimated Maximum Amount to be Iniected Daily The depletion plan for the Badami Reservoir requires the maintenance of reservoir pressure through voidage balance, or in other words injecting the same volume of liquid into the reservoir that is produced from it. There is no gas export from Badami, and after fuel gas has been removed, the remaining associated reservoir gas will be re-injected. Likewise, the produced water will be re-injected. Source water injection rates will vary with time and will be adjusted to maintain the voidage balance. The two source water wells have a combined capacity of30,000 barrels of water per day (bwpd). Reservoir simulations predict a maximum of26,000 bwpd of source water injection will be required. e e . e 3) Compatibility with Formation and Confining Zone SEM and XRD analyses conducted on Badami core samples indicate clay content of approximately 10 percent in reservoir intervals. Identified clay types include kaolinite, chlorite, illite, and mixed-layer illite/smectite. The content of the expandable mixed layer illite/smectite clays ranged from 0.1-1.7 percent. As a result, no significant problems associated with formation plugging or clay swelling are expected due to fluid incompatibilities. Produced Water Produced water is water that is produced with the Badami oil and separated from the oil and gas at the central process facilities (CPF). Produced water may contain trace amounts of scale inhibitor, corrosion inhibitor, emulsion breakers, and other products used in the production process. 1) Analysis of Composition of Typical Fluid Chemistry of the produced water from Badami is unknown at this time (prior to start up). However, for planning purposes the chemistry of the produced water has been estimated to be similar to produced water from the PBU GC-l well (see Exhibit J-2). 2) Estimated Maximum Amount to be Iniected Daily The maximum predicted produced water rate at Badami is 14,000 bwpd. 3) Compatibility with Formation and Confining Zone Since the origin of the produced water will be from the Badami sands, problems with formation plugging or clay swelling due to fluid incompatibilities are not anticipated. Miscible Hvdrocarbon Gas The miscible hydrocarbon gas will be a blend of the hydrocarbon gas associated with the oil produced by Badami, and a rich mixture of non-Badami gas and NGLs. The specific blend of Badami associated gas and non-Badami gas and NGLs will be regulated to ensure that miscibility between the injected gas and the reservoir fluids is maintained. 1) Analysis of Composition of Typical Fluid Exhibit J-3 shows the estimated composition of the miscible hydrocarbon gas. e e . e 2) Estimated Maximum Amount to be Iniected Daily The predicted rate of miscible hydrocarbon gas injection at Badami is 28 million scfd. 3) Compatibility with Formation and Confining Zone Fluid incompatibility problems are not anticipated with the miscible hydrocarbon gas. Other Fluids In addition to the fluids specifically associated with the EOR project, the following other incidental fluids may be injected into the Badami oil pool at some time during the life of the project. · sea water to thermally frac gas injection wells - stimulation procedure using 20,000- 40,000 gallons per well · gray water from the waste water treatment plant - for short periods when Class I disposal well not available (gray water may also be discharged to tundra) · ponded and/or storm water that may accumulate on the pad area - for short periods when Class I disposal well not available (some ponded/storm water may also be discharged to tundra) · solution gas associated with oil production - Badami gas will be re-injected for reservoir pressure maintenance prior to start up ofEOR process · tracer survey fluid - to monitor reservoir performance. e e .e Section K Injection Pressure 20 AAC 25.402(c)(10) The estimated maximum and average injection pressures anticipated for Badami wells are listed in the following table: Service Estimated Maximum Injection Pressure (Psig) Estimated Average Injection Pressure (Psig) Water injection 3500 3000 Gas injection 5500 5000 (Pressures represent pump discharge pressures) ee ·e Section L Fracture Information 20 AAC 25.402(c)(11) The estimated maximum injection pressures for Badami injection wells will not initiate or propagate fractures through the overlying confining strata, which might enable the injection or formation fluid to enter freshwater strata. Subsection 1 Freshwater Strata There is no freshwater strata in the area of issue (see Section N). Therefore, even if a fracture were propagated through all confining strata, injection or formation fluid would not come in contact with freshwater strata. Subsection 2 Enhanced Recovery Injection into the reservoir sands of Badami #5 appraisal well showed a frac gradient of 0.81 psi/ft. Data fracs of B 1-18 and B 1-21 both showed a frac gradient of 0.79 psi/ft. At the reservoir depth of 10,500 ft TVD, the frac pressure is therefore 8400 psi. Analysis of the array sonic log run in Badami #5 showed a stress contrast between the sands and the overlying shale of 1000 psi, putting the bottom hole pressure necessary to propagate a frac from the sands into the shale at 9400 psi. This was confirmed during the data frac ofBI-18. Injected water will have a lower temperature than the reservoir. This will lower the temperature of the sands it is injected into. This "thermal fraccing" effect will cause a reduction ofthe frac pressure of the zone being injected into. The thermoelastic contribution to the frac pressure is: L\Lth = E.a.(TinrTres)/(l-v) where a is the thermal expansivity ofthe rock (typically 8 x 10-6 OF-I), E is Young's modulus, measured from core at 3.5 - 4.5 x 106 psi and is v Poisson's ratio, measured from core at 0.25. Injected water is expected to have a temperature of 120°F at reservoir depth. Reservoir temperature is 185°F. Therefore long term injection of water is expected to drop the frac pressure of the sands by 2400 psi to 6000 psi. This will not affect the frac pressure of the shales as no water is entering the shale matrix and will not be cooling it. The shale frac pressure will remain 9400 psi. e_ -e Long term, the reservoir pressure will be allowed to drop by 1000 psi. This will cause a further drop in the frac pressure of 500 - 800 psi, to 5500 psi bottom hole. The maximum wellhead injection pressure while injecting water will be 3500 psi, the maximum pump output. This will give a bottom hole injection pressure of 8200 psi. At no time will this exceed the pressure necessary to propagate into the overlying shale. The necessary injection pressure will decrease with temperature effects and declining reservoir pressure. The maximum wellhead injection pressure while injecting gas will be 5500 psi. This will give a bottom hole pressure of 7000 psi, which is less than that exerted while injecting water. ee ·e Section M Formation Water 20 AAC 25.402(c)(12) No water bearing sands have been identified within the Badami oil pool, therefore, a reasonable estimate of total dissolved solids (TDS) for the Badami sands is not possible using data acquired to date. Water bearing sands are present in the formations above the Badami oil pool. As shown below, wire line log calculations indicate a lack of fresh water (equivalent NaCI concentration of less than 10,000 parts per million). The wells below are areally representative of the injection area and have wireline logs across the up-hole section. The method used in these calculations is described in Exhibit M -1. Well Depth Equivalent NaCI (TVDss) concentration (ppm) Badami 1 2253 41473 Badami 1 2907 44118 Badami 1 3444 48139 Badami 1 4342 33543 Badami 1 4932 30437 Badami 1 5190 34280 Badami 2 2000 37281 Badami 2 2133 35363 Badami 2 2162 39979 Badami 2 2253 40201 Badami 4 4539 30423 Badami 4 4822 29001 Badami 4 5104 27814 Badami 4 6971 16756 Badami 4 7058 18883 ee ·e Additionally, a shallow (4975-4989 TVDss) water sand (Sagavanirktok) in the Badami #5 well was tested in April 1995. The test results were used to evaluate whether these shallow saline aquifers could be used as a source of water for the EOR program. Laboratory analysis indicated that the NaCI concentration was 27000 ppm and the TDS concentration was 39,000 ppm. ee ·e Section N Aquifer Exemption 20 AAC 25.402(c)(13) The lack of fresh water and underground sources of drinking water (USDWs) in the Badami Injection Area eliminates the need for an aquifer exemption. The presence of hydrocarbons, either live or as residual, causes the Badami sands to be unsuitable as a source of drinking water. Calculations from wireline logs for the shallow water-bearing sands in the Badami # 1, 2 and 4 indicate equivalent NaCI concentrations greater than 10,000 ppm. Additionally, laboratory analysis of water produced from the a shallow sand in the Badami #5 well indicates an NaCI concentration of27,000 ppm and a TDS concentration of39,000 ppm (see Section M). On May 12, 1997, the EPA made a determination that there are no USDWs in the Badami filed area. Please see a copy of their determination in Exhibit N-l. ee ee Section 0 Hydrocarbon Recovery 20 AAC 25.402(c)(14) The Badami development scenario as currently planned includes a water alternating gas (WAG) flood. A total oil recovery of approximately 25 percent original oil in place (OOIP) is expected for this development scenario. This compares to an estimated 6 to 8 percent estimated OOIP recovery attributable to primary depletion and 12 to 20 percent estimated OOIP recovery attributable to primary depletion plus waterflood. ee ·e Section P Mechanical Integrity 20 AAC 25.402(d) & (e) In drilling all Badami injection wells, the casing is pressure tested in accordance with 20 AAC 25.030(g). Injection well tubing/casing annulus pressures will be monitored and recorded on a regular basis. BP, as operator of the Badami oil pool, will be responsible for the mechanical integrity of injection wells and for ensuring compliance with monitoring and reporting requirements. The tubing/casing annulus pressure of each injection well will be checked weekly as a routine duty to ensure there is no leakage and that it does not exceed a pressure that will subject the casing to a hoop stress greater than 70 percent ofthe casings minimum yield strength. If an injection well is deemed to have anomalous annulus pressure, it will be investigated for tubing/annulus communication using a variety of diagnostic techniques and a mechanical integrity test. If a subsequent investigation proves hydraulic communication between the tubing/casing exists, then a plan for remedial action will be formulated and scheduled. In addition, a variance will be obtained from the AOGCC to continue safe operations, if technically feasible, until the remedial solution is implemented. Tubing/casing pressure variations between consecutive observations need not be reported to the Commission. A schedule will be developed and coordinated with the Commission which ensures that the casing/annulus for each injection well is pressure tested prior to initiating injection. A test surface pressure of 1,500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, but not to exceed a hoop stress greater than 70% ofthe casing's minimum yield strength. The test pressure must be held for 30 minutes with no more than a 10 percent decline. The Commission will be notified at least 24 hours in advance to enable a representative to witness the pressure test. Alternative EP A approved methods may also be used, with Commission approval; including but not necessarily limited to timed-run radioactive tracer surveys (RTS), oxygen activation logs (OAL), temperature logs (TL), and noise logs (NL). An injection well located within the affected area will not be plugged or abandoned unless approved by the Commission in accordance with 20 AAC 25.105. ee ee Section Q Report on Mechanical Condition of Wells within Injection Area 20 AAC 25.402(h) To the best of BPXA's knowledge, the wells within the Badami pool area were constructed, and where applicable, have been abandoned to prevent the movement of fluids into freshwater sources. Exhibit A-I Exhibit A-2 Exhibit D-l Exhibit G-l Exhibit G-2 Exhibit G-3 Exhibit G-4 Exhibit 1-1 Exhibit J-l Exhibit J-2 Exhibit J-3 Exhibit M-l Exhibit N-l ee ee List of Exhibits Proposed Badami Injection Area - Existing and Proposed Wells Legal Description of Proposed Badami Injection Area Affidavit Badami # 1 Type Log Top Badami Sand (A-5) Structure Map West-East Structural Cross Section Badami Sands Isopach Map - Fan Systems 1,3,4,5 - CONFIDENTIAL Typical Badami WAG Injector Well Sagavanirktok Water Composition from Badami #5 Produced Water Composition Miscible Gas Composition Documentation of Water Salinity Calculations from Well Logs EP A Detennination Regarding USDWs #1 e e e e Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Badami Unit Enhanced Oil Recovery BP Exploration (Alaska) Inc. by letter dated June 1, 19'98 petitioned the Commission under 20 AAC 25.402 for an Area Injection Order for the underground injection of fluids for enhanced recovery in the Badami Unit, located east of Prudhoe Bay, on Alaska's North Slope. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM June 22, 1998, 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 hearing on the matter will be held at the above address at 9:00 AM on July 7, 1998, 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 June 22, 1998. If no protest is filed, the Commission will consider the issuance of the order without a hearing. 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 June 29, 1998. Published June 4, 1998 ADN AO 02814052 r DRI / MCGRAW HILL RANDALL NOTTINGHAM 24 HARTWELL LEXINGTON MA 02173 OVERSEAS SHIPHOLDING GRP ECON DEPT 1114 AV OF THE AMERICAS NEW YORK NY 10036 ALASKA OFC OF THE GOVERNOR JOHN KATZ STE 518 444 N CAPITOL NW WASHINGTON DC 20001 OIL DAILY CAMP WALSH 1401 NEW YORK AV NW STE 500 WASHINGTON DC 20005 US MIN MGMT SERV CHIEF OCS STATS & INFO 381 ELDEN ST MS 4022 HERNDON VA 20170-4817 . - ee ~J:D ~\1 PlRA ENERGY GROUP LIBRARY 3 PARK AVENUE (34TH & PARK) NEW YORK NY 10016 NY PUBLIC LIBRARY DIV E GRAND CENTRAL STATION POBOX 2221 NEW YORK NY 10163-2221 AMERICAN PETR INST STAT SECT JEFF OBERMILLER 1220 L ST NW WASHINGTON DC 20005 ARENT FOX KINTNER PLOTKIN KAHN LIBRARY WASHINGTON SQ BLDG 1050 CONNECTICUT AV NW WASHINGTON DC 20036-5339 LIBRARY OF CONGRESS STATE DOCUMENT SECTION EXCH & GIFT DIV 10 FIRST ST SE WASHINGTON DC 20540 U S DEPT OF ENERGY PHYLLIS MARTIN MS EI823 1000 INDEPENDENCE SW WASHINGTON DC 20585 US GEOL SURV LIBRARY NATIONAL CTR MS 950 RESTON VA 22092 AMOCO CORP 2002A LIBRARY/INFO CTR POBOX 87703 CHICAGO IL 60680-0703 LINDA HALL LIBRARY SERIALS DEPT 5109 CHERRY ST KANSAS CITY MO 64110-2498 MURPHY E&P CO ROBERT F SAWYER POBOX 61780 NEW ORLEANS LA 70161 .- ee TECHSYS CORP BRANDY KERNS PO BOX 8485 GATHERS BURG MD 20898 SD DEPT OF ENV & NATRL RESOURCES OIL & GAS PROGRAM 2050 W MAIN STE #1 RAPID CITY SD 57702 ILLINOIS STATE GEOL SURV LIBRARY 469 NATURAL RESOURCES BLDG 615 E PEABODY DR CHAMPAIGN IL 61820 ALFRED JAMES III 107 N MARKET STE 1000 WICHITA KS 67202-1811 UNIV OF ARKANSAS SERIALS DEPT UNIV LIBRARIES FAYETTEVILLE AR 72701 CROSS TIMBERS OPERATIONS SUSAN LILLY 210 PARK AVE STE 2350 OKLAHOMA CITY OK 73102-5605 IOGCC POBOX 53127 OKLAHOMA CITY OK 73152-3127 CH2M HILL J DANIEL ARTHUR PE PROJ MGR 502 S MAIN 4TH FLR TULSA OK 74103-4425 BAPI RAJU 335 PINYON LN COPPELL TX 75019 ee US DEPT OF ENERGY ENERGY INFORMATION ADMINISTRATION MIR YOUSUFUDDIN 1999 BRYAN STREET STE 1110 DALLAS TX 75201-6801 ee DWIGHTS ENERGYDATA INC JERLENE A BRIGHT DIRECTOR PO BOX 26304 OKLAHOMA CITY OK 73126 OIL & GAS JOURNAL LAURA BELL POBOX 1260 TULSA OK 74101 R E MCMILLEN CONSULT GEOL 205 E 29TH ST TULSA OK 74114-3902 MARK S MALINOWSKY 15973 VALLEY VW FORNEY TX 75126-5852 PURVIN & GERTZ LIBRARY 1201 MAIN ST STE 2600 DALLAS TX 75202 ee DEGOLYER & MACNAUGHTON MIDCONTINENT DIVISION ONE ENERGY SQ, STE 400 4925 GREENVILLE AVE DALLAS TX 75206-4083 GAFFNEY, CLINE & ASSOC., INC. ENERGY ADVISORS MARGARET ALLEN 16775 ADDISON RD, STE 400 DALLAS TX 75248 MOBIL OIL JAMES YOREK POBOX 650232 DALLAS TX 75265-0232 STANDARD AMERICAN OIL CO AL GRIFFITH POBOX 370 GRANBURY TX 76048 SHELL OIL CO J F CORDARO POBOX 2463 HOUSTON TX 77001 ee MOBIL OIL CORP MORRIS CRIM POBOX 290 DALLAS TX 75221 GCA ENERGY ADV RICHARD N FLETCHER 16775 ADDISON RD STE 400 DALLAS TX 75248 JERRY SCHMIDT 4010 SILVERWOOD DR TYLER TX 75701-9339 PRITCHARD & ABBOTT BOYCE B BOLTON PE RPA 4521 S. 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