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Home My WebLink AboutCO 802 AConservation Order 802A Beluga River Unit Beluga River Field Sterling-Beluga Gas Pool Kenai Peninsula Borough, Alaska 1. June 27, 2024 Hilcorp application to amend pool rules (CO 802) 2. July 12, 2024 Notice of Public Hearing and affidavit 3. May 5, 2025 Hilcorp Proposal to Revise Depths STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue Anchorage, Alaska 99501 Re: THE APPLICATION OF Hilcorp Alaska, LLC to vertically expand the limits of the Sterling-Beluga Gas Pool and the Alaska Oil and Gas Conservation Commission’s own motion to revise the Rule 4 Well Completions for clarity Beluga River Unit, Beluga River Field ) ) ) ) ) ) ) ) ) Docket Number: CO-24-010 Conservation Order 802A Beluga River Unit Beluga River Field Sterling-Beluga Gas Pool Kenai Peninsula Borough, Alaska October 29, 2024 IT APPEARING THAT: 1. By application received June 28, 2024, Hilcorp Alaska, LLC (Hilcorp), as operator of the Beluga River Unit (BRU), requested an amendment to Rule 2 of Conservation Order No. 802 (CO 802) to vertically expand the limits of the Sterling-Beluga Gas Pool (SBGP), within the BRU. On its own motion the Alaska Oil and Gas Conservation Commission (AOGCC) also proposes to revise Rule 4 of CO 802 to clarify what information is required to accompany a sundry application for perforating a well. 2. Pursuant to 20 AAC 25.540, the Alaska Oil and Gas Conservation Commission (AOGCC) tentatively scheduled a public hearing for September 3, 2024. On July 12, 2024, the AOGCC published notice of that hearing on the State of Alaska’s Online Public Notice website and on the AOGCC’s website, electronically transmitted the notice to all persons on the AOGCC’s distribution list. On July 17, 2024, the notice was also published in the Anchorage Daily News. 3. No public comments on the application nor a request to hold the hearing were received. 4. Hilcorp’s application contained sufficient information to allow the AOGCC to reach a decision without the need to hold the hearing. The tentatively scheduled hearing was vacated. FINDINGS: 1. Affected Area: The Affected Area of the SBGP was defined in CO 802 and Hilcorp’s application proposes no changes to the Affected Area. As currently mapped, approximately two-thirds of the 8,227.1 acres within the SBGP Affected Area lie onshore with the remainder offshore along the western side of the Cook Inlet Basin, Alaska. 2. Owners and Landowners: The owners of the BRU and the lands in the affected area are Hilcorp and Chugach Electric Association (CEA). Landowners are the State of Alaska Department of Natural Resources (DNR), the U.S. Bureau of Land Management (BLM), Cook Inlet Region Inc. (CIRI), CEA, and S&E Foster Properties, LLC. Ownership within the BRU changes with depth. From surface down to 7,000 feet, Hilcorp owns CO 802A October 29, 2024 Page 2 of 6 one-third working interest and CEA owns two-thirds working interest. Below 7,000 feet, CEA owns 100 percent working interest. The defined pool and proposed vertical expansion only include sands in the Sterling and Beluga Formations above the 7,000- foot depth. 3. Operator: Hilcorp is operator of all the leased acreage in the Affected Area. 4. Exploration and Delineation History: The SBGP was unexpectedly discovered by Standard Oil Company of California’s (Standard Oil) Beluga River No. 1 exploratory well (BR 1, since renamed BRU 212-35) that was drilled to 16,429 feet measured depth (MD) and true vertical depth (TVD) searching for oil in deeper objective horizons near the center of the present-day BRU. BR 1 provided the first indication that large quantities of gas had accumulated in the area when on April 28, 1962—while circulating at 3,249 feet MD after drilling a portion of the upper Sterling Formation—the well blew out, spewing mud, sand, rocks, water, and methane gas at an estimated rate of about 50 million cubic feet per day for more than nine hours. A subsequent Standard Oil press release, dated April 30, 1962, attributed the blowout to "an unexpected high-pressure, low-volume gas pocket." On December 3, 1962, after drilling, completing, and testing the well, Standard Oil announced a "significant gas discovery" in the BRU and reported that BR 1 tested 4.3 million cubic feet per day from about 4,800 feet MD. The well was subsequently completed on December 18, 1962 and shut in. From 1962 to 1964, four additional wells were drilled to delineate the field. Between December 1963 and May 1964 one of these wells, BRU 212-25, flowed a reported cumulative total of nearly 150.5 million cubic feet of gas from upper Sterling perforations between 3,437 and 4,111 feet MD (equivalent to about -3,395 and -4,069 feet TVDSS). Regular gas production began in March 1968. For the month of August 2024, production totaled slightly more than 1,325 million cubic feet of gas from 24 wells, an average daily rate of about 42.8 million cubic feet. Cumulative production from the field presently totals 1.4 trillion cubic feet. In addition, two disposal wells are active in the field; one is Class I and one is Class II. 5. Pool Identification: As currently defined, the SBGP encompasses Tertiary-aged, fluvial sediments assigned to the Sterling and Beluga Formations, and encompasses the interval in well BRU 224-13 (API Number 50-283-20042-00-00) from the measured depths (MD) of 3,345 to 7,000 feet, which are equivalent to about 3,241 and 6,896 feet TVDSS1. Hilcorp proposes to change these limits to 3,097 to 7,000 feet MD, which are equivalent to about 3,004 to 6,896 feet TVDSS. 6. Geology: a. Stratigraphy: As currently defined, the SBGP consists of about 3,650 true vertical feet of Tertiary- aged sediments deposited by braided and meandering rivers and streams that are assigned to the Sterling and Beluga Formations (in descending stratigraphic order). 1 The acronym TVDSS refers to true vertical depth subsea (true vertical depth below mean sea level). CO 802A October 29, 2024 Page 3 of 6 Sterling reservoir sands are generally thicker (up to 200 true vertical feet), often display broad lateral continuity, and typically have excellent reservoir quality (20 to 30 percent porosity and 100 to 2,000 millidarcy permeability), with little cementation. Reservoir sands assigned to the underlying Beluga are generally much thinner (3 to 50 true vertical feet), laterally discontinuous, isolated, lens-shaped bodies deposited by smaller rivers and streams. Beluga reservoirs are generally of lower reservoir quality, with 10 to 20 percent porosity, 1 to 200 millidarcy permeability, and often a moderate degree of cementation. Hilcorp proposes to add 234 true vertical feet of shallower sands in the Sterling formation to SBGP. b. Structure: The overall structure of the proposed pool is a northeast-trending, fault-propagation fold (anticline) that measures about 6-1/2 miles long and 2-1/2 miles wide, exhibits four-way dip closure, and is bound on the northwest by a high-angle reverse fault. c. Trap Configuration and Seals: Well log and seismic information indicate that the proposed pool is trapped structurally. Widespread interbeds of claystone, siltstone, and coal form top seals for individual gas reservoirs. d. Reservoir Compartmentalization: Compartmentalization occurs because of the nature of fluvial sediments, especially in the deeper Beluga portions of the proposed SBGP. To date, much of the production from the field has come from Sterling sands. 7. Reservoir Fluid Contacts: There are over 100 individual sands within the proposed expanded pool with various drive mechanisms and gas and water contacts (or lowest known gas when a water contact has not been detected). 8. Freshwater Wells and Shallow Aquifers: There are about 45 shallow water wells within and near the BRU according to the Alaska Department of Natural Resources’ Well Log Tracking System (WELTS) and U.S. Geological Survey databases. Most of these wells are concentrated near the mouth of Three Mile Creek in and near the southwestern corner of the BRU in Sections 8 and 9, T12N, R11W, SM. Several wells are clustered near the Beluga landing area in Section 34, T13N, R10W, SM. The remaining wells are scattered across the unit, lie just outside its northern and eastern unit boundaries, or have poorly documented locations. Depths reported for these shallow water wells range from 20 to 295 feet. Surface casing set and cemented in the BRU development gas wells at depths ranging from 1,982 to 3,386 feet below ground level protects these shallow drinking water wells and shallow aquifers. 9. Reservoir Fluid Properties (Datum: 4,000 feet TVDss): Initial reservoir pressure 2,215 psia Reservoir temperature 106o F Gas specific gravity 0.565 10. Reservoir Development Plan: Hilcorp currently plans to perforate Sterling Formation sands in the expansion interval in well BRU 232-04 (API Number 50-283-10023-00- CO 802A October 29, 2024 Page 4 of 6 00), as the SBGP is currently defined adding shallower perforations that would require a downhole commingling order in order to be able to production from the SBGP and these shallower sands at the same time. Hilcorp has identified four additional wells that may be completed in the expansion interval in the future. 11. Reservoir Management: Hilcorp plans to actively work to extend the life of the field and increase the ultimate recovery. As is typical for gas field developments in the Cook Inlet Basin, Hilcorp plans to develop reservoirs from the bottom up in the wells, opening and isolating sands as necessary to achieve economically viable production. This may often involve having multiple sand bodies open at the same time in order to maintain adequate production rates. The proposed expanded pool is nearly 4,000 feet thick. A pore pressure fracture gradient chart provided by Hilcorp with their application for previous order CO 802 indicates that potential exists for pressure from deeper sands to fracture shallower sands if too thick of an interval is open for production at the same time in the same well. Pressure observations in the proposed expansion interval do not appear to be abnormally pressured when compared to the existing SBGP. 12. Reservoir Surveillance Plans: Hilcorp did not propose a specific reservoir surveillance plan for the SBGP or the proposed expansion interval and thus will need to comply with the annual plan of reservoir development and operation plan requirements of 20 AAC 25.517. Similarly, Hilcorp did not propose a specific reservoir pressure monitoring program for the SBGP or the proposed expansion interval and will have to report quarterly any bottomhole pressure survey data that is collected for the pool on the Reservoir Pressure Report (Form 10-412). Pressures will be referenced to a datum of 4,000 feet TVDSS. CONCLUSIONS: 1. Expanding the vertical limits of the SBGP to include the shallower Sterling Formation sands that Hilcorp plans to target to determine if they are developable reservoirs is appropriate for Hilcorp’s continued development of the BRU SBGP. 2. The BRU is a very mature field that had been successfully developed in accordance with statewide regulations, other than a plethora of spacing exceptions, for the majority of the field life and with CO 802 in recent years. As such, development of the potential reservoirs in the shallower Sterling Formation sands in accordance with the SBGP pool rules will benefit from the pool rules to ensure continued successful development. 3. Well spacing not restricted by internal property boundaries or minimum between-well distances will increase flexibility in placing wells, facilitate more efficient resource recovery, and will not promote waste, jeopardize correlative rights, or result in an increased risk of fluid movement into freshwater aquifers. 4. Correlative rights of owners and landowners of offset acreage will be protected by a 1,500-foot set-back requirement from boundaries where the ownership and/or landownership changes. 5. Limitations on the thickness of intervals that can be open for production at the same time are necessary in order to ensure that shallower zones are not fractured by production from deeper formations should the well be shut in and crossflow occur. CO 802A October 29, 2024 Page 5 of 6 6. Drinking water wells and shallow freshwater aquifers within the proposed Affected Area of the SBGP are protected by surface casing and cement. 7. Hilcorp’s proposed Administrative Action rule is unnecessary since administrative actions for AOGCC-issued orders are now authorized by AOGCC regulation 20 AAC 25.556(d). 8. Revising Rule 4 is necessary to more clearly articulate what information is required to be submitted with a sundry application to perforate a well in the BRU. NOW THEREFORE IT IS ORDERED: Development and operation of the Beluga River Unit, Sterling-Beluga Gas Pool is subject to the following rules and the statewide requirements under 20 AAC 25 to the extent not superseded by these rules. CO 802 is hereby superseded by this order and its record incorporated by reference: Affected Area: Seward Meridian (Source CO 802) Township and Range Section(s): Portion(s): T12N, R10W 2 NW1/4NW1/4 3 NW1/4, NE1/4, SW1/4, N1/2SE1/4, SW1/4SE1/4 4 All 9 NW1/4, NE1/4, E1/2SW1/4, N1/2SE1/4, SW1/4SE1/4 10 NW1/4, NW1/4NE1/4, NW1/4SW1/4 T13N, R9W 7 S1/2SW1/4, SW1/4SE1/4 18 NW1/4, W1/2NE1/4, SW1/4, NW1/4SE1/4 19 N1/2NW1/4, SW1/4NW1/4, NW1/4SW1/4 T13N, R10W 13 S1/2NW1/4, NE1/4, SW1/4, SE1/4 14 S1/2SW1/4, SE1/4 22 E1/2NE1/4, SE1/4SW1/4, SE1/4 23 & 24 All 25 NW1/4, W1/2NE1/4, N1/2SW1/4, SW1/4SW1/4 26 All 27 S1/2NW1/4, NE1/4NW1/4, NE1/4, SW1/4, SE1/4 33 E1/2NE1/4, E1/2SE1/4 34 & 35 All 36 W1/2NW1/4 CO 802A October 29, 2024 Page 6 of 6 Rule 1 Field and Pool Name (Source CO 802) The field is the Beluga River Field. Hydrocarbons underlying the Affected Area and within the interval identified in Rule 2, below, constitute the Beluga River Unit, Sterling-Beluga Gas Pool. Rule 2 Pool Definition (Revised this order) The Beluga River Unit, Sterling-Beluga Gas Pool is defined as the accumulation of gas common to and correlating with the interval between 3,097 to 7,000 feet MD, which are equivalent to about 3,004 and -6,896 feet TVDSS, in reference well BRU 224-13 (API Number 50-283-20042- 00-00). Rule 3 Well Spacing (Source CO 802) Within the Affected Area there shall be no restrictions as to well spacing except that no pay shall be opened in a well within 1,500 feet of the exterior boundary of the Affected Area described above or within 50 vertical feet of the 7,000-foot deep vertical lease boundary where ownership and/or landownership changes. Rule 4 Well Completions (Revised this Order) When proposing to add perforations to a well, the operator must submit a pore pressure/fracture gradient review and calculated shallowest allowable perforation with the sundry application to demonstrate that the proposed operation will not result in fractures propagating in any zone due to crossflow should the well be shut in. DONE at Anchorage, Alaska and dated October 29, 2024. Jessie L. Chmielowski Gregory C. Wilson Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.28 18:06:26 -06'00' Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.29 03:58:11 -08'00' From:Coldiron, Samantha J (OGC) To:AOGCC_Public_Notices Subject:[AOGCC_Public_Notices] Conservation Order 802A (Hilcorp) Date:Tuesday, October 29, 2024 8:17:57 AM Attachments:co802a.pdf THE APPLICATION OF Hilcorp Alaska, LLC to vertically expand the limits of the Sterling- Beluga Gas Pool and the Alaska Oil and Gas Conservation Commission’s own motion to revise the Rule 4 Well Completions for clarity Beluga River Unit, Beluga River Field Samantha Coldiron AOGCC Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1223 __________________________________ List Name: AOGCC_Public_Notices@list.state.ak.us You subscribed as: samantha.coldiron@alaska.gov Unsubscribe at: https://list.state.ak.us/mailman/options/aogcc_public_notices/samantha.coldiron%40alaska.go v 3 May 2, 2025 Wayne Svejnoha, Chief Branch of Energy & Minerals Bureau of Land Management 222 West Seventh Avenue #13 Anchorage, Alaska 99513-7504 RE: Proposal to Revise Depths Beluga-Sterling Participating Area Beluga River Unit Kenai Peninsula Borough, AK Dear Mr. Svejnoha: Hilcorp Alaska, LLC (“Hilcorp”), is in receipt of the Notice of Written Order of the BLM Authorized Officer dated April 22, 2025, requiring Hilcorp to submit a written request to: a) expand the Beluga River Unit Beluga-Sterling Participating Area (“BRU PA”), including supporting documentation, and b) address alleged production from the BRU 232-04 and BRU 222-24 on a lease-basis. Hilcorp, as Operator of the Beluga River Unit (“BRU”), hereby respectfully proposes to the Bureau of Land Management (“BLM”) to revise the BRU PA depths to reflect those same depths established in Conservation Order (“CO”) 802A Sterling-Beluga Gas Pool (“SBGP”) as that interval between 3,097’ MD (3,004’ TVDSS) to 7,000’ MD (6,896’ TVDSS) as identified in the BRU 224-13 (API No. 502832004200). x Including shallower Sterling Formation sands above the current top of the BRU PA allows for the continued development of the field by targeting smaller, undrained portions of the identified reservoir; thereby maximizing the ultimate hydrocarbon recovery while ensuring the continued protection of correlative rights of the affected parties. x The basis to vertically expand the BRU PA is derived from analysis of five (5) BRU wells in which the shallower Sterling sands were observed to not be abnormally pressured compared to those in within the depths of the currently defined BRU PA. In support of the vertical expansion of the top of the BRU PA, please see the table below depicting observed pressures in their respective wells, of which Hilcorp anticipates seeing similar results in planned BRU development: 3800 Centerpoint Dr., Suite 1400 Anchorage, AK 99503 Direct: (907) 777-8432 Email: luke.suchecki@hilcorp.com By Samantha Coldiron at 8:39 am, May 05, 2025 Well Name MD TVDSS Formation Pressure (psi) Formation Date 232-09 4,015’ -3,218’ 1395 Pre Sterling A Oct-1985 232-09 4,086’ -3,274’ 1417 Pre Sterling A Oct-1985 214-26 3,015’ -2,828’ 1202 Pre Sterling A Sep-1990 214-26 3,037’ -2,849’ 1228 Pre Sterling A Sep-1990 214-26 3,058’ -2,869’ 1221 Pre Sterling A Sep-1990 214-26 3,067’ -2,878’ 1227 Pre Sterling A Sep-1990 214-26 3,077’ -2,887’ 1373 Pre Sterling A Sep-1990 214-26 3,101’ -2,910’ 1237 Pre Sterling A Sep-1990 214-26 3,112’ -2,921’ 1241 Pre Sterling A Sep-1990 214-26 3,125’ -2,933’ 1247 Pre Sterling A Sep-1990 214-26 3,152’ -2,959’ 1259 Pre Sterling A Sep-1990 212-35T 2,996’ -2,815’ 1214 Pre Sterling A Sep-1998 212-35T 3,018’ -2,836’ 1224 Pre Sterling A Sep-1998 212-35T 3,043’ -2,860’ 1234 Pre Sterling A Sep-1998 212-35T 3,104’ -2,919’ 1232 Pre Sterling A Sep-1998 212-35T 3,128’ -2,942’ 1241 Pre Sterling A Sep-1998 212-35T 3,147’ -2,961’ 1243 Pre Sterling A Sep-1998 212-35T 3,167’ -2,980’ 1251 Pre Sterling A Sep-1998 211-26 3,747’ -2,870’ 1226 Pre Sterling A Aug-2008 211-26 3,824’ -2,920’ 1228 Pre Sterling A Aug-2008 211-26 3,897’ -2,968’ 1241 Pre Sterling A Aug-2008 242-04 3,622’ -2,995’ 1225 Pre Sterling A Jun-2012 244-23 4,006’ -3,114’ 1303 Pre Sterling A Jul-2012 As of the date of this proposal, Hilcorp maintains that all BRU production is allocated BRU PA accurately, meaning production has not required reporting on a lease-basis allocation. For that reason, non-PA is inconsequential: BRU 232-04 (API No. 502831002300) Hilcorp perforated the BRU 232-04 in the proposed expanded zone depths on January 19, 2025; however, there are no volumes to report as production. The BRU 232-04 is the only well perforated above existing top of the BRU PA. BRU 222-24 (API No. 502832018000) The BRU 222-24 was drilled to the Bottom Hole Depth of 7,627’ MD (-6996’ TVDSS). The deepest produced interval in the BRU 222-24 was from 6,472 – 6,493’ MD, being above the base of both the SBGP and BRU PA. The table below displays the current perforations depths and their respective dates: Well Name MD Top MD Base Date 222-24 5,289’ 5,293’ 08/08/2024 222-24 5,296’ 5,301’ 08/08/2024 222-24 5,314’ 5,320’ 08/08/2024 222-24 5,345’ 5,352’ 08/08/2024 222-24 5,657’ 5,673’ 08/08/2024 Through this written request, Hilcorp has demonstrated that the current depth of the top of the BRU PA (3,354’ MD) should be expanded vertically upward to include those shallower Sterling formation sands (3,097’ MD), and that all produced volumes have been appropriately reported as BRU PA production. The revision of depths for the BRU PA is appropriate because expanded depths represent the area reasonably estimated to be productive in paying quantities. Should you require additional information, please contact the undersigned with any questions. Sincerely, Luke Suchecki Landman CC: Chait Borade, CIRI Samantha Coldiron, AOGCC Will Maercklein, BLM Sharon Yarawsky, BLM 2 Notice of Public Hearing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RE: Docket Number: CO-24-010 By applications dated June 27, 2024, Hilcorp Alaska, LLC (Hilcorp), as the operator of the Beluga River Unit (BRU), requests that the Alaska Oil and Gas Conservation Commission (AOGCC) expand the vertical extent of the Sterling-Beluga Gas Pool (S-BGP), as currently defined by Rule 2 of Conservation Order No. 802 (CO 802) in the BRU. CO 802 defines the S-BGP and prescribes rules for its development. Hilcorp proposes to amend this order to expand the vertical extent of the S-BGP to include shallower sands in the Sterling Formation that aren’t currently part of the pool. This notice does not contain all the information filed by Hilcorp. To obtain more information, contact the AOGCC’s Special Assistant, Samantha Coldiron, at (907) 793-1223 or samantha.coldiron@alaska.gov. A public hearing on the matter has been tentatively scheduled for September 3, 2024, at 10:00 a.m. The hearing, which may be changed to full virtual, if necessary, will be held in the AOGCC hearing room located at 333 West 7th Avenue, Anchorage, AK 99501. The audio call-in information is (907) 202-7104 Conference ID: 245 399 369#. Anyone who wishes to participate remotely using MS Teams video conference should contact Ms. Coldiron at least two business days before the scheduled public hearing to request an invitation for the MS Teams. To request that the tentatively scheduled hearing be held, a written request must be filed with the AOGCC no later than 4:30 p.m. on July 31, 2024. If a request for a hearing is not timely filed, the AOGCC may issue an order without a hearing. To learn if the AOGCC will hold the hearing, call (907) 793-1223 after August 2, 2024. In addition, written comments regarding this application may be submitted to the AOGCC, at 333 west 7th Avenue, Anchorage, AK 99501 or samantha.carlisle@alaska.gov. Comments must be received no later than 4:30 p.m. on August 22, 2024, except that, if a hearing is held, comments must be received no later than the conclusion of the September 3, 2024, hearing. If, because of a disability, special accommodations may be needed to comment or attend the hearing, contact Samantha Coldiron, at (907) 793-1223, no later than August 27, 2024. Jessie L. Chmielowski Commissioner Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.12 13:41:43 -08'00' From:Coldiron, Samantha J (OGC) To:AOGCC_Public_Notices Subject:[AOGCC_Public_Notices] Public Hearing Notices Date:Friday, July 12, 2024 2:42:06 PM Attachments:CO-24-010 public hearing notice expansion of S-BGP in BRU.pdf CO-24-009 and AIO-24-019 public hearing notice establishing pool rules and an AIO for the COP in KRU.pdf AIO-24-018 public hearing notice establishing an AIO for the KROP in SMU.pdf Docket Number: AIO-24-018 By application dated June 3, 2024, Mustang Holding LLC (Mustang), as the operator of the Southern Miluveach Unit (SMU), requests that the Alaska Oil and Gas Conservation Commission (AOGCC) approve an Area Injection Order (AIO) to allow enhanced oil recovery (EOR) injection activities in the portion of the Kuparuk River Oil Pool (KROP) located in the SMU. Docket Numbers: CO-24-009 and AIO-24-019 By application dated June 20, 2024, ConocoPhillips Alaska, Inc. (CPAI), as the operator of the Kuparuk River Unit (KRU), requests that the Alaska Oil and Gas Conservation Commission (AOGCC) approve Pool Rules establish rules for the development of the Coyote Oil Pool (COP) in the KRU and an Area Injection Order (AIO) to allow enhanced oil recovery (EOR) injection activities in the COP. Docket Number: CO-24-010 By applications dated June 27, 2024, Hilcorp Alaska, LLC (Hilcorp), as the operator of the Beluga River Unit (BRU), requests that the Alaska Oil and Gas Conservation Commission (AOGCC) expand the vertical extent of the Sterling-Beluga Gas Pool (S-BGP), as currently defined by Rule 2 of Conservation Order No. 802 (CO 802) in the BRU. Samantha Coldiron AOGCC Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1223 __________________________________ List Name: AOGCC_Public_Notices@list.state.ak.us You subscribed as: samantha.coldiron@alaska.gov Unsubscribe at: https://list.state.ak.us/mailman/options/aogcc_public_notices/samantha.coldiron%40alaska.go v Lisi Misa being first duly sworn on oath deposes and says that she is a representative of the An- chorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the afore- said place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on AFFIDAVIT OF PUBLICATION ______________________________________ Notary Public in and for The State of Alaska. Third Division Anchorage, Alaska MY COMMISSION EXPIRES ______________________________________ 07/17/2024 and that such newspaper was regularly distrib- uted to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. Signed________________________________ Subscribed and sworn to before me Account #: 100869 ST OF AK/AK OIL AND GAS CONSERVATION COMMISSION333 W. 7TH AVE STE 100, ANCHORAGE, AK 99501 Order #: W0047008 Cost: $314.67 Notice of Public HearingSTATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSION RE: Docket Number: CO-24-010 By applications dated June 27, 2024, Hilcorp Alaska, LLC (Hilcorp), as the operator of the Beluga River Unit (BRU), requests that the Alaska Oil and Gas Conservation Commission (AOGCC) expand the vertical extent of the Sterling-Beluga Gas Pool (S-BGP), as currently defined by Rule 2 of Conservation Order No. 802 (CO 802) in the BRU. CO 802 defines the S-BGP and prescribes rules for its development. Hilcorp proposes to amend this order to expand the vertical extent of the S-BGP to include shallower sands in the Sterling Formation that aren’t currently part of the pool. This notice does not contain all the information filed by Hilcorp. To obtain more information, contact the AOGCC’s Special Assistant, Samantha Coldiron, at (907) 793-1223 or samantha.coldiron@alaska.gov. A public hearing on the matter has been tentatively scheduled for September 3, 2024, at 10:00 a.m. The hearing, which may be changed to full virtual, if necessary, will be held in the AOGCC hearing room located at 333 West 7th Avenue, Anchorage, AK 99501. The audio call-in information is (907) 202-7104 Conference ID: 245 399 369#. Anyone who wishes to participate remotely using MS Teams video conference should contact Ms. Coldiron at least two business days before the scheduled public hearing to request an invitation for the MS Teams. To request that the tentatively scheduled hearing be held, a written request must be filed with the AOGCC no later than 4:30 p.m. on July 31, 2024. If a request for a hearing is not timely filed, the AOGCC may issue an order without a hearing. To learn if the AOGCC will hold the hearing, call (907) 793-1223 after August 2, 2024. In addition, written comments regarding this application may be submitted to the AOGCC, at 333 west 7th Avenue, Anchorage, AK 99501 or samantha.carlisle@alaska.gov. Comments must be received no later than 4:30 p.m. on August 22, 2024, except that, if a hearing is held, comments must be received no later than the conclusion of the September 3, 2024, hearing. If, because of a disability, special accommodations may be needed to comment or attend the hearing, contact Samantha Coldiron, at (907) 793-1223, no later than August 27, 2024. Jessie L. Chmielowski Commissioner Pub: July 17, 2024 STATE OF ALASKA THIRD JUDICIAL DISTRICT ______________________________________2024-07-19 2028-07-14 Document Ref: DT9YN-EWAGQ-ZQCBO-S2GHR Page 9 of 23 1 By Samantha Coldiron at 8:25 am, Jun 28, 2024