OGJ Newsletter

GENERAL INTEREST Quick Takes

TotalEnergies to withdraw from Myanmar

TotalEnergies SE will withdraw from Myanmar citing worsening human rights conditions. The company belongs to joint ventures in the Yadana gas project off Myanmar’s southwestern coast and the MGTC pipeline that carries gas from Yadana field to the Burmese-Thai border.

TotalEnergies initiated the contractual process of withdrawing from Yadana and MGTC, both as operator and as shareholder, without any financial compensation. This withdrawal will be effective at the latest at the expiry of the 6-month contractual period. The agreements also stipulate that, in the event of withdrawal, TotalEnergies’ interests will be shared between the current partners, unless they object to such allocation, and that the role of operator will be taken over by one of the partners. During this notice period, TotalEnergies will continue to act as a responsible operator to ensure continuity of gas deliveries, it said.

Yadana field produces around 6 billion cu m/yr gas of which about 70% is exported to Thailand where it is sold to PTT and 30% is retained by Burmese state-owned Myanmar Oil and Gas Enterprise (MOGE) for domestic use.

TotalEnergies is operator of Yadana (Blocks M5 and M6) (31.24%). Partners include Chevron affiliate Unocal Myanmar Offshore Co. Ltd. (UMOCL) (28.26%), PTT Exploration & Production Public Co. Ltd (25.5%), and MOGE (15%). The shareholders of MGTC are the same as the partners in Yadana field and in the same proportions.

Chesapeake names Viets EVP, COO

Chesapeake Energy Corp., Oklahoma City, has appointed Josh Viets as executive vice-president and chief operating officer, effective Feb. 1.

For the last 20 years, Viets has worked in operational positions at ConocoPhillips Co. He most recently served as vice-president, Delaware basin and previously held leadership positions in operations, engineering, subsurface, and capital project across the ConocoPhillips portfolio.

Continental Resources names new COO

Bill Berry, chief executive officer of Continental Resources Inc., Houston, will become president and chief executive officer of the Oklahoma City-based company following the retirement of Jack Stark, the company’s president and chief operating officer.

Stark, who joined the company in 1992 and served in various leadership roles over the last 30 years, will retire by late spring and transition into a part-time consulting role as a senior advisor to Berry.

Doug Lawler has been named chief operating officer and executive vice-president, effective Feb. 1. Lawler has spent over three decades in the oil and gas industry, beginning with Kerr-McGee in 1988. Most recently, Lawler was president and chief executive officer of Chesapeake Energy from 2013 to 2021.

Phillips 66 expands into lithium-ion battery business

Phillips 66 has inked a technology development agreement with affiliate Novonix Ltd. to advance production and commercialization of next-generation anode materials used to produce lithium-ion batteries as part of the downstream operator’s strategy to support lower-carbon technologies.

Under the Jan. 19 agreement, Novonix and Phillips 66—a global manufacturer of specialty coke, a key precursor to synthetic graphite anode material Novonix produces—will leverage their existing intellectual property and research and development (R&D) capabilities to drive commercial expansion of optimized feedstock and lithium-ion anode materials with reduced carbon-intensive processing, the companies said.

The partnership will focus on establishing a North American supply chain to power the growing lithium-ion battery sector, where Novonix’s US business already has plans under way to provide large volumes of synthetic graphite anode material, according to Chris Burns, Novonix’s chief executive officer.

“[T]ogether we plan to develop integral processes, from manufacturing precursor materials to producing high-capacity long-life synthetic graphite anode material intended to improve battery performance, lower cost, and decrease environmental impact,” Burns said

For Phillips 66, the collaboration follows its September 2021 acquisition of a 16% stake in Novonix as an investment to support scaled up production and development of new technologies for higher-performance energy storage applications, reinforcing both companies’ commitments to a lower-carbon future, according to Ann Oglesby, Phillips 66’s vice-president of research and innovation.

Phillips 66—one of the few downstream companies with an in-house R&D organization—is carrying out the collaboration through its Energy Research & Innovation group, which works on developing lower-carbon technologies—including next-generation batteries—to support the energy transition.

Based in Chattanooga, Tenn., Novonix plans to increase its capacity to produce synthetic graphite anode material for lithium-ion battery manufacturing to 10,000 tonnes/year (tpy) by 2023; 40,000 tpy by 2025; and 150,000 tpy by 2030, the company said.

Exploration & Development Quick Takes

Frontera finds hydrocarbons at Jandaya-1 in Ecuador

Frontera Energy Corp. is preparing permits to move forward with a long-term test after finding hydrocarbons at the Jandaya-1 exploration well on the Perico block in Ecuador.

The Jandaya-1 exploration well was spud Dec. 7, 2021, to test an exploration prospect in the northeastern portion of the block. The well was drilled to a total depth of 10,975 ft (3,345 m) and a total of 78 ft vertical depth of potential hydrocarbon bearing reservoir was encountered in three formations.

The initial 24-hour test average flow rate for the Lower Hollin formation was about 750 b/d and 1 MMcfd of gas for a total of 925 boe/d with an average water cut of 17%. Well clean up and additional flow testing in two other zones will be completed in the coming weeks.

An environmental impact assessment is being prepared and additional appraisal activities are expected to be performed in the short-term to confirm size and mid- to long-term production levels, the operator said.

Additionally, Frontera expects to spud the Tui-1 exploration well in the southern portion of the Perico block in February. Tui-1 lies about 6 km from the Jandaya-1 well and is expected to be drilled to a total depth of 10,972 ft. Additional prospects on the Perico block have been identified and are being matured for future drilling.

Frontera holds about 16,700 net acres in the Perico and Espejo exploration blocks in Ecuador. The blocks lie near existing production and infrastructure in Sucumbíos Province in the northeastern part of Ecuador, in the Oriente basin. The basin currently produces more than 500,000 b/d.

Frontera is operator of the Perico block with 50% interest. GeoPark Ltd. holds the remaining 50%.

Carnarvon reports disappointing Buffalo-10 results

Carnarvon Energy Ltd. noted a 12 m gross oil column interpreted from data gained from logging-while-drilling tools from its Buffalo-10 appraisal well in the Timor Sea.

The well, in Timor Leste production sharing contract area TL-SO-T 19-14, reached a total depth of 3,415 m and the LWD tools identified that the primary reservoir has been intersected.

The top Elang reservoir was reached at around 3,338 m, which was about 80 m low to prognosis and outside the pre-drill range of expectations, the company said.

“The information to date indicates that the seismic processing techniques employed on this project have not resolved the underlying seismic velocity distortion or imaging resolution issues that are present in Buffalo field,” the company added.

The forward plan is to run wireline logs to determine the reservoir properties and confirm a net oil column.

Buffalo-10 was designed to evaluate the presence of what was hoped to be a significant accumulation of attic oil in the field, left after the original field production was shut in. Carnarvon said last year that the subsea interpretation had been supported using full waveform inversion technology to reprocess the 3D seismic data acquired over the prospect.

Carnarvon farmed out a 50% interest in the Buffalo redevelopment project to Advance Energy PLC in December 2020 and has been free-carried for the first US$20 million of well costs. Carnarvon retained 50% interest and operatorship.

Buffalo field was discovered by BHP in 1996 when the permit was in Australian jurisdiction and brought on stream in 1999. It produced 20.5 million bbl of oil until shut in by Nexen in 2004.

When the Timor Sea marine boundary was redrawn in 2019, Buffalo came under East Timor jurisdiction.

KUFPEC makes first operated offshore exploration discovery

Kuwait Foreign Petroleum Exploration Co. subsidiary KUFPEC Indonesia (Anambas) BV made a commercial discovery of gas and condensate in the Anambas block, offshore Indonesia.

The Anambas-2X well—the first operated offshore exploration discovery for KUFPEC—was drilled in 288 ft of water using a jack up rig to reach a total depth of 10,509 ft.

The block lies in the Natuna Sea near a block in which KUFPEC is a partner.

As part of the drilling campaign, KUFPEC Indonesia conducted two drill stem tests so far, one in the Lower Gabus formation and the other in the Intra Keras formation. These tests resulted in a stabilized combined flow rate of 7 MMscfd of natural gas and 1,240 b/d of condensate from the two formations. Additional tests on other formations within the same well are planned.

Upon reaching its main drilling objective in the Lower Gabus Formation, KUFPEC Indonesia utilized well deepening operation techniques to successfully penetrate thicker and cleaner reservoirs. The outcomes identified potential further exploration opportunities in the deeper formations. KUFPEC Indonesia will also continue implementing testing programs for three reservoirs in the Arang formation, which could produce higher gas rates.

KUFPEC Indonesia is operator of the block with 100% participating interest.

Sinopec signs award for Iraq gas field development

The Iraqi Ministry of Oil let a contract to Sinopec Petroleum & Chemical Corp. to develop Mansuriya gas field near the border with Iran.

The contract term is 25 years with the possibility of a 5-year extension. Sinopec will develop two wells in the field and will finance all exploration, assessment, development, and production activities.

Phased production will begin with 50 MMscfd and will continue toward targeted production of 300 MMscfd. The 150-sq km field is estimated to hold gas reserves of 4.5 trillion standard cu ft. 

“The field will provide enough gas to generate 1000 Megawatts of electricity,” said Minister of Oil Ihsan Abdul-Jabbar Ismail.

A contract to develop the field was won in 2010 by a consortium of Korea Gas Corp. (Kogas), Kuwait Energy, and Turkish Petroleum International Co. (TPAO), but work was not started due to area security concerns at the time (OGJ Online, Oct. 20, 2010). The Ministry of Oil reintroduced the field in the sixth licensing round in 2021, which was awarded to Sinopec.

Sinopec is operator (49%) with state-owned Basra Oil Co. holding the remaining 51%.

Drilling & Production Quick Takes

Turonian drilling campaign at Yuzhno-Russkoye completed

Severneftegazprom, a joint venture of Gazprom, Wintershall Dea, and OMV, concluded the Turonian drilling campaign that began in 2018.

The JV completed drilling the 100th well in the formation of Yuzhno-Russkoye field in Western Siberia and this year plans to complete the tie-in for all Turonian wells drilled so far.

Gas production from the formation is aimed at complementing production from the Cenomanian deposits and prolonging the plateau production from the field.

Severneftegazprom—the only company in Russia to develop the Turonian deposits on a commercial scale—has so far produced 10 billion cu m of Turonian gas, most of it in 2021.

Wintershall operates the Severneftegazprom JV, which produces 25 billion cu m/year of natural gas for Western Europe from Yuzhno-Russkoye field. The field lies about 3,500 km northeast of Moscow in the Yamal-Nenets Autonomous Area.

The field consists of four rock strata containing natural gas and oil: Cenomanian, Turonian, Lower Cretaceous, and Jurassic. Natural gas has been produced from the Cenomanian deposits since 2007. Booster systems are used to counteract the natural drop in pressure and decline in production.

Norway production increased in December, NPD says

Norway’s liquids production averaged 2.108 million b/d in December, the Norwegian Petroleum Directorate (NPD) reported Jan. 20.

Norway’s liquids production averaged 1.999 million b/d in November (OGJ Online, Dec. 27, 2021).

Oil production in December is 0.2% lower than the NPD’s forecast, and 0.4% higher than the forecast so far this year. Total gas sales were 10.9 billion std cu m, which is an increase of 0.5 billion std cu m from the previous month.

Average daily liquids production in December consists of 1.841 million b/o, 267,000 bbl of NGL and condensate, and 353.1 million std cu m/d gas.

The total volume is 4.0 higher than the 2020 figures.

PetroNeft increases drilling, completion activity in Western Siberia

PetroNeft Resources PLC will expand a stimulation program at Tungolsky license 61 and start a drilling program at Ledovy license 67 in the Tomsk Region of Western Siberia.

PetroNeft expanded a 5-well reservoir stimulation program in license 61 to seven wells for first-quarter 2022. NewTech Well Services LLC will perform the stimulations based on the original five-well contract signed on Nov. 12, 2021.

Successful reservoir stimulation of L-115 well (Lineynoye field) and S-373 well (Sibkrayevskoye field) last year provided technical information for program expansion. Six wells will be in Lineynoye field, and one will be in Arbuzovskoye field. Overall production is expected to increase 350-650 b/d from the seven-well program.

PetroNeft has let a contract to Siberian Oil Service Co. (SSK) for drilling of up to five wells at Cheremshanskoye field in license 67. The wells will be a combination of vertical and horizontal development wells from the northern pad, adjacent to the producing C-4 well.

Ledovy license 67 lies in the main oil-bearing region of the Tomsk Oblast west of the Ob River and has 14 million bbl net 2P reserves. Tungolsky license 61 is on the east side of the Ob River containing seven oil fields and over 25 identified prospects and leads. It is the least explored oil-bearing region of the Tomsk Oblast. Estimated 2P reserves are 117.05 million bbl.

PetroNeft is operator of license 67 (90%) with partner Belgrave Naftogas BV (10%). PetroNeft is also operator of license 61 (50%) with partner Oil India Ltd. (50%).

Kuwait Energy ties in Al Jahraa well

Kuwait Energy Egypt has tied in the Al Jahraa-13 development well (AJ-13) in the Abu Sennan license, 7 km north of producing Al Jahraa field in Egypt’s Western Desert, partner United Oil & Gas PLC said in a Jan. 13 release.

AJ-13, the fifth and final well in the Abu Sennan 2021 drilling program, reached a TD of 3,840 m, days ahead of schedule and under budget. The well has been logged and interpreted to have encountered 17.5 m of net oil pay across Upper and Lower Bahariya reservoir targets, in line with pre-drill expectations (OGJ Online, Dec. 29, 2021).

The well has been tied into existing infrastructure and brought on stream at an initial rate of 623 b/d oil and 0.47 MMscfd gas on a 48/64-in. choke and 897 b/d oil and 0.95 MMscfd gas on a 64/64-in. choke.

The ECDC-6 rig will now move to drill the ASD-2 development well, the first well in the 2022 campaign. ASD-2 well follows the exploration success made in 2021 with the ASD-1X well. It will target the Abu Roash reservoirs in a more northerly part of the same structure, aiming to access the upside reserves and accelerate production from the field.

Abu Sennan is operated by Kuwait Energy Egypt (25%). Joint venture partners are United Oil & Gas (22%), Global Connect Ltd. (25%), and Dover Investments (28%).

Talos hits quarterly, full-year record high production in 2021

Talos Energy Inc., Houston, produced an average 67,500-69,000 boe/d in fourth-quarter 2021 and an average 64,000-64,500 boe/d for full-year 2021, representing new quarterly and annual record highs.

Fourth quarter production was above the previously indicated range due to better than expected uptime and was about 69% oil and 77% liquids.

Capital expenditures for fourth-quarter 2021 were $63-68 million, near the low end of its previously issued full year capital guidance range.

The company repaid an additional $25 million of debt from the company’s credit facility in the quarter, bringing the yearend facility balance to $375 million, a $90 million reduction from Mar. 31, 2021.

The operator will release additional details in its fourth-quarter 2021 results earnings release on Feb. 24.

PROCESSING Quick Takes

ExxonMobil, SABIC start up new US Gulf Coast chemical complex

Saudi Arabian Basic Industries Corp. (SABIC) and ExxonMobil Corp. have reached official startup of their 50-50 joint venture Gulf Coast Growth Ventures LLC’s (GCGV) ethane cracker and derivatives complex in Portland, San Patricio County, Tex., near Corpus Christi (OGJ Online, July 26, 2021).

Commercially operating as of Jan. 20, GCGV’s complex—including its 1.8-million tonnes/year (tpy) ethane cracker, 1.1 million-tpy monoethylene glycol unit, and two polyethylene units with combined capacity of 1.3 million tpy—will help meet growing global demand for performance products with its production of raw materials used for packaging, agricultural film, construction materials, clothing, and automotive coolants, SABIC and ExxonMobil said in separate releases.

Start of commercial operations at the site follows mechanical completion of the complex’s units in July 2021 and confirmation in June 2021 by Paul Fritsch—GCGV’s plant manager—that all units at the site would enter the commissioning phase by yearend 2021 (OGJ, Aug. 2, 2021, p. 35; OGJ Online, Nov. 10, 2021).

Completed ahead of schedule and below budget, GCGV’s complex—which marks SABIC and ExxonMobil’s first JV in the Americas—was formed in 2018 to take advantage of the US Gulf Coast’s existing infrastructure to capture competitive pricing for US natural gas feedstock and access to rising demand for ethylene-based products in overseas export markets (OGJ Online, June 13, 2019).

Alongside forming part of SABIC’s growth strategy to build petrochemical installations in global key markets, the multibillion GCGV project also forms a cornerstone of ExxonMobil’s previously announced 10-year, $20-billion Growing the Gulf expansion initiative announced in early 2017 (OGJ Online, Mar. 9, 2017).

LUKOIL’s Perm refinery lets contract for new MTBE, alky plant

PJSC LUKOIL has let a contract to Lummus Technology LLC to license technologies and provide equipment for a grassroots plant that will produce blending components for production of cleaner, high-octane gasoline to be built at subsidiary LLC LUKOIL-Permnefteorgsintez’s 13.1-million tonnes/year (tpy) refinery in Russia’s North Urals region, on the north bank of the Kama River (OGJ Online, Aug. 20, 2021).

As part of the contract, Lummus will deliver technology licensing, basic engineering, technical services, and proprietary equipment supply for a new integrated methyl tertiary butyl ether (MTBE) and alkylation plant, the service provider said on Jan. 14.

The MTBE unit will use Lummus’ CDEtherol technology, with the alkylation unit to be equipped with the technology licensor’s proprietary CDAlky technology.

Alongside enabling LUKOIL to improve production quality, lower utility-energy consumption, and reduce maintenance requirements, the CDEtherol and CDAlky technologies all will allow the Perm refinery flexibility to produce biofuels in the future, Lummus said.

The service provider revealed neither a value of the contract nor planned capacities of the proposed greenfield plant.

This latest contract for fuel upgradation works at Perm follows LUKOIL’s recent contract awards to Honeywell UOP LLC to deliver licensing and equipment for new units to be added as part of the refinery’s planned grassroots FCC complex that, due for startup in 2026, will enable the site to covert 1.8 million tpy of low-value vacuum gas oil into high-octane motor gasoline and polymer-grade propylene (OGJ Online, Jan. 13, 2022; Sept. 9, 2021).

Louisiana awards grant to support proposed Caldwell Parish renewables fuel plant

The Port of Columbia has received a $15-million grant from the government of Louisiana for improvements intended to support development of Strategic Biofuels LLC’s proposed grassroots renewable fuels plant on a 171-acre tract of land at the port, in Caldwell Parish, about 25 miles south of Monroe (OGJ Online, Apr. 26, 2021).

Awarded by the Louisiana Department of Transportation and Development-administered Louisiana Port Construction and Development Priority Program, the infrastructure improvement grant will enable road, rail, and traffic flow upgrades at and around the port that will allow Strategic Biofuels to advance its aggressive construction schedule for subsidiary Louisiana Green Fuels LLC’s (LGF) planned renewable fuels plant, the parties said on Jan. 19.

Actual plant construction is scheduled to begin as soon as full project funding is secured, which Strategic Biofuels expects to occur in early 2023, said Bob Meredith, Strategic Biofuels’ chief operating officer.

First announced in early 2021, the LGF-operated plant would use established refinery processes to produce up to 32 million gal/year of renewable fuel from a feedstock of wood waste made up of timber byproducts supplied by responsibly managed, sustainable plantation forests within Louisiana.

The proposed project also would feature carbon capture and storage (CCS), or sequestration, which—combined with its sustainably sourced feedstock—would enable LGF’s plant to produce renewable diesel in a carbon-negative fashion.

Strategic Biofuels, which previously received a $200-million tax-free bond allocation from the state of Louisiana to help advance the estimated $700-million development, completed its CCS test well program for LGF’s renewable diesel fuel project in third-quarter 2021, the company said in an Aug. 11, 2021, release.

Based on its most recent timeline, Strategic Biofuels said it plans to reach mechanical completion of the LGF plant in mid-2025 for targeted full-commercial operation in late 2025.

Once operational, LGF’s refinery would produce about 83% renewable diesel and 17% renewable naphtha chemically identical to fossil-derived diesel and naphtha.

Norwegian biofuels producer lets contract for proposed plant study

Orbit Origo AS subsidiary Biojet AS has let a contract to KBR Inc. to deliver a concept study for the operator’s proposed project to build a renewable fuels production plant in Ringerike, Norway.

As part of the early works contract, KBR will provide technology evaluations, early engineering, and project development for the plant, which will be designed to convert a feedstock of forestry residues into renewable and sustainable green fuels, the service provider said on Jan. 24.

KBR confirmed Biojet’s proposed Ringerike plant comes as part of the operator’s aim to supply the European market with renewable fuels by 2026.

The Biojet contract award follows the Jan. 11 announcement from ExxonMobil Corp. that it has acquired a 49.9% ownership interest in the Norwegian biofuels producer as part of the global company’s broader effort to deliver lower-emission fuels and products to the transportation sector.

Acquisition of the Biojet stake additionally supports ExxonMobil’s plans to deliver the global market more than 40,000 b/d of lower-emission fuels by 2025 and 200,000 b/d by 2030 to help reduce carbon dioxide (CO2) emissions from the transportation sector by more than 25 million tonnes/year as announced in its Advancing Climate Solutions 2022 Progress Report (ACS) published on Jan. 18.

Alongside purchasing a 49.9% stake in the Norwegian renewables company, ExxonMobil said it also signed offtake agreements allowing it to purchase up to 3 million bbl/year of products from Biojet’s five proposed manufacturing plants, all of which will convert forestry and wood-based construction waste into lower-emissions biofuels and biofuel components that meet requirements for advanced fuels under Norwegian, European Union, and United Kingdom regulations.

Upon announcing acquisition of Biojet shares, Ian Carr—president of ExxonMobil Fuels and Lubricants Co.—said ExxonMobil will be able to use its access at the site of subsidiary Esso Norge AS’ recently shuttered 116,000-b/d refinery at the port of Slagen—now a fuel import terminal—to distribute biofuels throughout Norway, as well as to countries across northwest Europe.

TRANSPORTATION Quick Takes

US Appeals Court vacates Equitrans’ Mountain Valley pipeline permits

The US Fourth Circuit Court of Appeals has reversed US Forest Service (USFS) and Bureau of Land Management (BLM) approvals related to Equitrans Midstream Corp.’s Mountain Valley natural gas pipeline’s still pending 3.5-mile crossing of the Jefferson National Forest. The court found that USFS and BLM had failed to properly predict and prevent erosion and sedimentation occurring during the pipeline’s construction to date.

The Forest Service and BLM must now reconsider the permits, a process which could take more than a year.

The 303-mile, 2-bcfd Mountain Valley pipeline is more than 90% complete and Equitrans had hoped to put it in service during 2022, already 4 years later than originally planned.

Judge Stephanie Thacker wrote in the unanimous decision that “because the Forest Service did not sufficiently consider the Pipeline’s actual sediment and erosion impacts…the amendments to the Jefferson Forest Plan may not maintain soil and riparian resources within the scope of the 2012 Planning Rule. And because the Forest Service does not have a clear indication from FERC about the environmental impacts of the use of the conventional bore method to cross the four streams within the Jefferson National Forest, it is unclear whether the amendments to the Jefferson Forest Plan [would] maintain the forest’s resources, as the 2012 Planning Rule intended.”

Texas LNG, Enbridge to expand Valley Crossing pipeline

Texas LNG Brownsville LLC, a controlled subsidiary of Glenfarne Group LLC developing a 4-million tonne/year LNG plant in the Port of Brownsville, Tex., and Enbridge Inc. agreed to expand the Valley Crossing pipeline (VCP) to deliver 720 MMcfd of natural gas to Texas LNG for a term of at least 20 years.

VCP consists of a 160-mile, 42- and 48-in. OD pipeline from Agua Dulce hub in Texas to the Port of Brownsville. A 10-mile lateral will be built to extend the pipeline to Texas LNG and compression added to the existing pipeline.

Agua Dulce interconnects with ten major gas pipeline systems transporting gas from the Permian and other basins with a total receipt capacity of more than 7 bcfd. Compression added at Agua Dulce will use electric motors, reducing CO2 emissions, according to Texas LNG.

Texas LNG expects to achieve final investment decision in 2022 and commercial operations in 2026.

Enterprise to acquire Navitas Midstream

An affiliate of Enterprise Products Partners LP, Houston, has agreed to acquire Navitas Midstream Partners LLC from an affiliate of Warburg Pincus LLC in a debt-free transaction for $3.25 billion in cash.

This acquisition provides Enterprise’s natural gas processing and NGL business with an entry point into the Midland basin of the Permian. The system is anchored by long-term contracts and acreage dedications with a group of over 40 independent and publicly owned producers and supported by fee-based contracts.

Navitas Midstream’s assets include about 1,750 miles of pipelines and over 1 bcfd of cryogenic natural gas processing capacity with the completion of the Leiker plant, which is expected in this year’s first quarter, growing to over 1.3 bcfd in first-half 2023. The deal includes up to 10,000 remaining drilling locations on dedicated acreage and no exposure to federal lands.