Consumer Assistance | Energy | Telecom | Warehouse | Commission Actions | Miscellaneous

SOUTH DAKOTA PUBLIC UTILITIES COMMISSION
2025 Highlights

Leadership
Chairman Chris Nelson
Vice Chairperson Kristie Fiegen
Commissioner Gary Hanson

Electric & Natural Gas Rate Changes & Adjustments
Energy Efficiency
Corporate Merger
Siting
Telecommunications
Legislation
 Leadership
Regional Transmission Organizations
Public Outreach and Consumer Assistance
 Grain Warehouse
Pipeline Safety

ELECTRIC & NATURAL GAS RATE CHANGES & ADJUSTMENTS

Reviewing electric and natural gas rates from around the state, region and nation offers perspective to evaluate the financial impact of South Dakota ratepayers’ experience compared to residents in other states.

  • The commission processed several transmission cost recovery tariff requests in 2025 with these results:

    • In February, Otter Tail Power Co.’s updated transmission cost recovery rider rate was approved by the commission. The updated rate allows for recovery of nearly $2.8 million related to six previously approved projects, regional transmission expenses and revenues, and an updated transmission demand allocation factor. The company’s request also included returning an estimated $286,687 from over-collection to customers. Otter Tail estimates a residential customer using 1,000 kWh per month will see a monthly bill increase of approximately $0.42 as a result of the change. See docket EL24-034.

    • In March, the commission signed off on MidAmerican Energy’s updated TCR rider rate. The updated rates are based on true ups to the actual over/under recovery from 2024, 2025 forecasted Midcontinent Independent System Operator transmission expense, and the forecasted over/under recovery for January through March of 2025. The new rate, effective April 1, 2025, resulted in a typical residential customer using 700 kWh per month seeing a $0.30 per month increase in their monthly bill. See docket EL25-004.

    • In April, the PUC approved Montana-Dakota Utilities Co.’s annual update to its TCR rider. The revised rate of negative $0.00127 per kWh allows for the recovery of MISO and SPP expenses net of revenues, net of the Basin Facility Agreement and Rate 45 revenue, but does not include any new projects. Compared to the previous rate, a typical residential customer using 900 kWh per month will see an increase of $0.80 per month or $9.60 per year. When combined with the company’s updated Infrastructure Rider Rate, that same customer will see a net decrease of $0.40 per month or $4.80 annually. See docket EL25-006.

    • In December, the commission approved an updated transmission cost recovery rider rate for Xcel Energy. The updated rate included costs associated with 22 transmissions projects, including one new project, and MISO Schedule 26 revenues and expenses. The approved $2,475,901 revenue translates to a monthly bill increase of approximately $0.47 for a typical residential customer using 750 kwh per month. Costs and a determination related to the Minnesota Energy Connection project have been deferred to a later date pending the outcome of the filed rate case. See docket EL25-031.

  • In April, the commission approved Montana-Dakota Utilities Co.’s annual update to its infrastructure rider rate. The update approved a 2025 Infrastructure Rider revenue requirement of $356,083 associated with two new projects, the rebuild of the Wishek Transmission Substation and upgrades to the SCADA system, recovery of a Regulatory Asset, and a projected over collection from the previous year. As a result of the change, a typical residential customer using 900 kWh per month will see a decrease of $1.20 per month, or $14.40 per year. When combined with the company’s updated Transmission Cost Recovery Rate, that same customer will see a net decrease of $0.40 per month or $4.80 annually. See docket EL25-007.

  • In May, the commission approved Otter Tail Power Co.’s annual update to its Phase-in Rider rate with a total revenue requirement of $3,198,356. The revenue requirement is recovered in two parts, with the revised “percent of bill” phase-in rider factor of 9.863% and per meter rates that vary by customer class. The updated rates allow Otter Tail to recover costs associated with the Astoria, Merricourt, and Ashtabula III wind projects, Abercrombie Solar and Solway Solar projects, Lake Norden Area load growth credit, savings associated with the retirement of the Hoot Lake Plant, four wind repower projects at Langdon, Luverne, Ashtabula I and Ashtabula III, new advanced metering infrastructure, outage management system, and demand response system. As a result of the update, a residential customer with one residential meter who uses 1,000 kWh a month will see a monthly bill decrease of $0.68. See docket EL24-038.

  • In June, the commission received and began processing an application from Otter Tail Power Co. for approval to increase rates for approximately 11,500 electric service customers in its South Dakota service territory by over $5.7 million annually or approximately 12.5% based on Otter Tail’s 2024 historic test year. The company stated a typical residential customer using 932 kWh per month would see an increase of approximately $14.39 per month. Interim rates were implemented in December. (Following extensive discovery, negotiations and research, the company and PUC staff reached a comprehensive agreement on all issues and submitted it to the commission for consideration in March 2026. After additional inquiry, Commissioners Nelson and Fiegen voted to approved the submitted settlement stipulation allowing for an electric base rate increase below the company’s original ask. Commissioner Hanson was unable to be present for the vote. As a result of the approval, a typical residential customer using 932 kWh per month would see an estimated increase of $8.97 in their monthly bill, significantly less than the original request.) See docket EL25-022.

  • Xcel Energy filed an application with the PUC in June, requesting approval to increase rates for electric service to its approximately 107,000 South Dakota customers by approximately 15% or $43.6 million annually. Additionally, the filing included specific requests to roll the costs of certain projects currently being recovered through infrastructure and transmission cost recovery riders into base rates that would result in a gross overall base rate increase of $63.4 million. As a result of the changes, the company estimates a typical residential electric customer using 756 kWh per month would see an average monthly bill increase of about $20.56 or 18.66%. One intervenor participated in the docket process. A decision is expected in 2026. See docket EL25-024.

  • In July, the PUC approved NorthWestern Energy’s request to implement a phase-in rate plan rider. The approved rider plan will allow NorthWestern to recover costs associated with two new modular simple cycle natural gas combustion turbines located at the Aberdeen Generation Station site, along with the study and evaluation of Small Modular Nuclear Reactor (SMR) technology to meet future generation and capacity needs. The plan has a total revenue requirement of $4,277,952 and will also remove costs that are currently recovered in base rates that are associated with assets that will soon be retired. As a result of the rider, a typical residential electric customer using an average of 750 kWh per month will see a bill increase of $2.11 per month. See docket EL25-013.

ENERGY EFFICIENCY

  • The commission approved updates to energy efficiency and conservation programs. In 2025, the estimated energy savings for investor-owned utilities with energy efficiency programs were 11,739 megawatt hours of electricity and 4,322 dekatherms of natural gas.

    • The PUC approved a revised conservation tracking adjustment rate of $0.016 per dk for Montana-Dakota Utilities Co. in February. MDU’s conservation program provides incentives to residential customers using high-efficiency heating equipment and programmable thermostats. As a result of the updated rate, the estimated annual increase for a residential customer using 70 dk annually is $0.14. The natural gas program also offers rebate options for commercial customers. See docket NG25-001.

    • Otter Tail Power Co. continued its energy efficiency plan in 2025. In June, the commission approved the 2024 financial incentive, 2024 energy efficiency plan status report and updated the energy efficiency adjustment factor. As a result of the revised energy efficiency adjustment factor, an average residential customer using 927 kWh per month should see an increase of $0.49 in their monthly bill. See docket EL25-021.

    • In December, Xcel Energy’s 2026 demand side management plan, 2026 cost adjustment factor, 2024 status report, 2024 DSM tracker account, and the performance incentive earned in 2024 were approved by the commission. The 2026 DSM plan includes changes to the Business Saver’s Switch program and a new Commercial HVAC+R program. Changes also include the removal of the Residential Lighting program and changes to the Residential Demand Response program to focus on accommodating new installations and growing the base of customers participating in the Saver’s Switch offering. All Xcel customers collectively share the cost of the DSM program. An average residential customer using 750 kWh per month will see a monthly bill decrease of $0.02. See docket EL25-020.

CORPORATE MERGER

In October, Black Hills Corp. and NorthWestern Energy Group and NorthWestern Energy Public Service Corp. dba NorthWestern Energy filed a joint application with the commission for approval of a corporate merger of their companies. The filing started the clock on the 180-day period within which the PUC must issue a final decision on the filing, as dictated by state law. In early December, the three-member panel granted South Dakota Laborers Local 620, the Great Plains Laborer’s District Council, and the Laborers International Union of North America’s petition to intervene. (A procedural schedule was established in January 2026. In February, following a motion and agreement by all parties, the commissioners agreed to extend the statutory deadline past 180 days and set the new deadline for July 27, 2026.) See docket GE25-001.

SITING

The PUC has authority to issue permits for the construction of energy conversion, AC/DC conversion, wind energy, solar energy, and electric transmission facilities as well as certain pipelines, including those designed to transport coal, gas, liquid hydrocarbon products, carbon dioxide or hydrogen.

  • POTENTIAL FUTURE SITING PROJECTS

    • In August, Crowned Ridge Energy Storage I, LLC (CRES) filed a petition with the commission requesting the panel issue a declaratory ruling finding the PUC does not have the statutory authority to require a facility permit for the construction and operation of an energy storage facility. The company plans to construct a 120-MW energy storage facility in Codington County with an anticipated commercial operation date of December 2027. After review of the facts presented through filings, oral arguments and further inquiry by commissioners, the PUC found, with Commissioner Nelson dissenting, that CRES did not clearly establish that the energy storage facility is not an energy conversion facility. In October, the commission issued an order denying the company’s petition in accordance with the commission’s findings, thereby requiring CRES to file for a permit. See docket EL25-027.

    • Following the decision in EL25-027, Crowned Ridge Energy Storage I filed a notice of intent to apply for a permit for an energy conversion facility with the PUC in mid-October. The company plans to construct a 120-megawatt, four-hour Battery Energy Storage System in Codington County. The project is proposed to be located on approximately 15.4 acres within the existing Crowned Ridge I Wind Energy Facility project area and connected to the existing Crowned Ridge Wind Collector Substation through an approximately 1,355 foot collection line. Crowned Ridge plans to build the energy storage facility on property with a voluntarily executed lease with a purchase option agreement. In November, the Commission issued an order that established the affected area and designated a local review committee. See docket EL25-034.

  • SITING APPLICATIONS

    • In January, the PUC approved a settlement stipulation and granted a permit for the construction of the Big Stone South to Alexandria Transmission Line Project, a 345-kV transmission facility and associated facilities in Grant County. The permit included 34 conditions that were proposed in the settlement agreement from PUC staff and joint applicants Otter Tail Power Co. and Western Minnesota Municipal Power Agency. The project will begin at Otter Tail’s existing Big Stone South Substation two miles west of Big Stone City, South Dakota, and connect to a substation near Alexandria, Minnesota. The South Dakota portion of the project will consist of approximately 3.5 miles of transmission line. The applicants submitted their request to the commission in April 2024. A public input meeting was held Big Stone City in May 2024. Daniel and Tamra Jurgens were granted party status in the docket, and entered into a settlement agreement with the applicants and withdrew from the docket. See docket EL24-015.

    • In March, the commission granted Deuel Harvest Wind Energy South LLC a permit to construct the South Deuel Wind Project wind energy facility in Deuel County. The action was taken following a January evidentiary hearing in Pierre. The proposed project is expected to have a nameplate capacity not to exceed 260 megawatts and includes up to 68 wind turbines and a six-mile 345-kilovolt generator tie line. More than 50 conditions addressing a wide array of requirements the company will need to comply with while constructing, operating and maintaining the project were included in the PUC’s order. Topics like agricultural operations and agricultural spray applicators in the area, habitat for threatened or endangered species, shadow flicker, noise levels, road use, reclamation, ice detection and decommissioning were among some of the issues addressed by the conditions. See docket EL24-023.

    • In November 2024, the PUC received SCS Carbon Transport LLC’s application for a permit to construct and operate a carbon dioxide transmission pipeline. The proposed project planned to span five states, and include approximately 2,500 miles of pipelines for the transportation of CO2 from more than 30 ethanol plants, including 15 in South Dakota. Approximately 698 miles of pipeline would be placed in the state, crossing 23 counties. The PUC held public input meetings in Mitchell, Sioux Falls, De Smet, Watertown, Aberdeen and Redfield in January that were collectively attended by more than 1,500 people. The commission received more than 600 applications for party status in this docket and approved over 500 intervenors to formally participate in the docket. On March 6, Gov. Larry Rhoden signed House Bill 1052, prohibiting the use of eminent domain for carbon oxide pipelines, into law. Following that action, Summit Carbon Solutions filed a motion to suspend the procedural schedule in this docket and extend deadlines indefinitely. Landowners filed a motion in late March requesting the PUC deny the application. A hearing was held on April 10, 2025, to address the motions during which the commission denied Summit’s request and deferred the motion from intervenors. On April 22, 2025, after hearing from all parties, commissioners found that the route put forth in the application was no longer viable and voted 2-1, with Commissioner Nelson dissenting, to deny Summit’s permit application. See docket HP24-001.

    • Western Minnesota Municipal Power Agency and Missouri River Energy Services filed an application to construct an energy conversion facility and electric transmission line, known as the Toronto Power Plant project, in Deuel County, South Dakota, in August. The proposed project plans to consist of a 145-megawatt dual fuel power plant and 345-kilovolt generation-tie transmission line. The power plant will include four combustion turbine-generator sets, a turbine hall building, diesel fuel truck unloading facilities, and other associated facilities. The 345-kV generation-tie transmission line will be approximately 4.9 miles long and will connect the power plant with the existing Astoria 345-kV substation. Associated facilities will include natural gas piping anticipated to be less than 450 feet. The project is proposed to be in commercial operation in 2029. The applicants estimate the total construction cost to be $378 million. A public input meeting was held in Toronto in September. A final decision from the commission is expected in 2026. See docket EL25-028.

    • In August, the commission received and began processing Philip Wind Partners, LLC’s application for a permit to construct a wind energy facility in Haakon County. The proposed project plans to span 68,300 acres and if built to full capacity, would be capable of generating up to 333 megawatts of energy, making it the largest wind project in the South Dakota to date. In addition to up to 87 turbines, the $750 million project plans include an approximate 5.5-mile long 230-kV generator transmission tie line, a 34.5-kV electrical collection and supervisory control and data acquisition systems, a 230-kV collector substation, an operations and maintenance facility, up to three aircraft detection lighting system towers, access roads, and up to three meteorological towers. The PUC held a public input meeting in Philip in October. (The company, along with PUC staff, submitted a joint settlement stipulation agreeing the applicant met the requirements for a permit that was approved by the commission in February 2026. The approved agreement incorporated 55 conditions and granted the applicant a permit to construct the Philip Wind Project.) See docket EL25-029.

    • The commission began processing Basin Electric Power Cooperative’s transmission facility permit application in August. The application illustrated Basin Electric’s proposal to construct a 0.95-mile, single-circuit 230-kV transmission line extension in Haakon County. The project extends between the new Philip North Switchyard, to be constructed by Western Area Power Administration, and a dead-end transmission structure that will cut into the existing transmission line connected to the Philip Tap switching station. It will include construction of up to seven three-phase, single circuit transmission structures constructed on steel H-frame and monopole structures and will include up to four pulling and tensioning sites. The company estimates the total construction cost of the proposed Project to be $2.48 million. The PUC held a public input meeting in Philip in October. (In early February 2026, PUC staff and the applicant reached an agreement on all issues and submitted a joint settlement for the commission’s consideration. Commissioners voted unanimously to approve the agreement at a regular meeting, granting Basin Electric a permit to construct and clearing the way for the project to move forward.) See docket EL25-030.

TELECOMMUNICATIONS

  • Twenty-six telecommunications carriers were deemed eligible to collectively receive millions of dollars in high-cost support from the federal Universal Service Fund for maintaining, upgrading and building out their voice and broadband networks in South Dakota. Each year, the commission must certify to the Federal Communications Commission that these carriers, designated as Eligible Telecommunications Carriers, are using funds for the provision, maintenance and upgrading of facilities and services for which support is intended. Dollars invested reflect the strengthening and expansion of telecommunications infrastructure to enhance system reliability and enable more service options to more customers, particularly in rural areas. The Universal Service Administrative Co. distributed over $122.7 million in High-Cost Support and over $1.6 million in Lifeline and Link-Up monies to South Dakota companies.

  • In December, commissioners and staff attended the South Dakota Telecommunications Association/Public Utilities Commission Educational Forum in Sioux Falls. The event brought together telecommunications professionals from across the state to collaborate and connect. Topics of discussion included broadband, technology and regulatory issues.

LEGISLATION

  • In January, PUC commissioners and staff invited senators and representatives to join them for the annual PUC Briefing for Legislators. The briefing provided an opportunity for Commissioners Nelson, Fiegen and Hanson to share information on current topics with lawmakers including energy regulation, rate cases, siting, telecommunications, broadband, pipelines, regional transmission organizations and grain warehouses. It also gave commissioners an opportunity to discuss the PUC’s proposed legislation.

  • The PUC’s legislation, House Bill 1007, eliminated ambiguity in state law as to how the PUC will be reimbursed for costs incurred in processing a siting permit. The bill allows the PUC to seek timely compensations, pay its expenses and removes risks to ratepayers.

  • House Bill 1008, the commission’s legislation to include a hybrid facility as a facility to be regulated by the Public Utilities Commission, passed and was signed into law. The bill clarifies that a generation facility comprised of more than one type of generation, such as a combination of wind and solar, that has a total output of 100 megawatts or more does require a PUC siting permit.

LEADERSHIP

Commissioners hold a number of leadership roles with national and regional organizations. They also engage with South Dakota consumers, students, industry professionals and community leaders during many public gatherings each year.

  • SOUTH DAKOTA PUC

    • Commissioner Kristie Fiegen kicked off a new term in January by taking the oath of office. Her oath was administered by South Dakota Supreme Court Chief Justice Steven R. Jensen in the Supreme Court Chambers in the State Capitol. Fiegen was re-elected by South Dakota voters in November 2024 and will serve in the elected post until 2031.

    • Commissioners selected Commissioner Gary Hanson to lead the PUC as chairman and Commissioner Chris Nelson to serve as vice chairman. Hanson made the decision to step back from the leadership role while he began treatments for cancer in the fall and elected to pass the gavel to fellow commissioner Chris Nelson. Nelson stepped into the role of chairman in November and Commissioner Fiegen transitioned to vice chairperson.

    • In July, Leah Mohr was appointed the new executive director of the PUC. She took the helm following Patricia Van Gerpen’s retirement. Mohr had served as the commission’s deputy executive director since 2009 and had worked for the PUC for a total of 19 years. Van Gerpen’s retirement closed the book on an exceptional 20 years with the PUC and 41 years working in South Dakota state government. Finance manager Cindy Kemnitz was promoted to fill the vacancy of Mohr’s former position while continuing her role as chief financial officer.

    • Commissioners also recognized that a change in executive leadership was an opportune time to evaluate the needs of the commission, the structure in place, look at best practices used in similar regulatory agencies across the country and determine if the PUC could benefit from their implementation. After much consideration, it was determined that some organizational restructuring would benefit the office. As a result, certain responsibilities were reassigned to streamline processes and a new operations specialist role was created.

  • PUBLIC ENGAGEMENT

    • Commissioner Nelson educated and shared his expertise as a speaker, panelist and moderator at events hosted by the National Association of Regulatory Utility Commissioners, the Organization of MISO States, National Association of Counties, Center for Public Utilities, South Dakota Telecommunications Association, South Dakota Rural Electric Association, Osher Lifelong Learning Institute, Western Dakota Technical College, Wisconsin Public Utility Institute, NorthWestern Energy, Stanley County Commission, North Central Electric Association and Grand Electric Cooperative, among others. Topics included broadband, Universal Service Fund spending, renewable energy, generation and transmission, energy security and the general role and happenings at the PUC. Nelson also found time to connect with industry representatives at events like an Xcel Energy ribbon cutting, and with students and community groups from across the state like Civil Air Patrol and Junior Achievement.

    • Commissioner Fiegen regularly met with students of all ages to share her passion for public service. She met with and discussed the PUC, the roles of the legislature and state government, the importance of ethics and leadership in proper governing and careers with students from Newell, Sioux Falls’ Roosevelt and Jefferson High Schools, legislative pages and interns and several groups involved in South Dakota’s Job’s for America’s Graduates program. She, together with Commissioner Nelson, also shared the role of the PUC and discussed leadership with Chamberlain Middle School Explorers students and South Dakota Civil Air Patrol. Fiegen is an active member of Southwest Power Pool and holds numerous leadership positions within the organization. At the organizations’ Energy Synergy Summit, she spoke on managing load growth, the importance of planning and forecasting and grid modernization. Fiegen delivered a keynote speech on grid resilience planning for extreme cold and ice related weather events at a NARUC regional training. She also moderator several panel discussions at industry events: a discussion on Reliable and Sustainable Distribution Pipeline Systems at the National Association of Regulatory Utility Commissioners Summer Policy Summit in Boston and another related to innovations in planning and technology for natural gas systems at the Mid-America Regulatory Conference annual meeting in Indianapolis. Commissioner Fiegen also met with numerous utility industry groups throughout the year, keeping them up to date on topics like electric reliability, happenings at the PUC, regional transmission organizations, policy or regulation changes, and other related topics.

    • Commissioner Hanson is an active member of the Advisory Council for New Mexico State University’s Center for Public Utilities and participated in the CPU’s Current Issues conference in Sante Fe, New Mexico, in April. The New Mexico State University program, one of only four university centers with programs endorsed by the National Association of Regulatory Utility Commissioners, provides training programs and current policy issues conferences to meet the needs of professionals employed at federal and state commissions, utility companies, and other stakeholders in the electricity, natural gas distribution, interstate pipeline, water utility and telecommunications industries.

REGIONAL TRANSMISSION ORGANIZATIONS

In the United States, a regional transmission organization is an electric power transmission system operator that coordinates, controls and monitors a multi-state electric grid. These non-profit corporations were voluntarily created, following a December 20, 1999, order by the Federal Energy Regulatory Commission (FERC) for the purpose of promoting economic efficiency, reliability, and nondiscriminatory practices while reducing government oversight. The transfer of electricity among states is considered interstate commerce and electric grids spanning multiple states are therefore regulated by FERC. Regional Transmission Organizations (RTOs) and Independent System Operators (ISOs) also operate competitive wholesale electricity markets, where electricity generators bid their supply into the market and the lowest-cost bids are dispatched first. The maps below provide a look at the regional transmission organizations and markets that affect South Dakota and the utility companies that participate in each.

RTOs and ISOs use a stakeholder process for decision making and policy setting, and state public utilities commissions have a crucial seat at the stakeholder table. The PUC actively participates in the Southwest Power Pool, Midcontinent Independent System Operator, and California Independent System Operator’s Western Energy Imbalance Market stakeholder processes to advocate on behalf of South Dakotans and the state’s electric utilities as issues arise. This participation is time consuming, with commissioners and staff devoting many hours of their week to work on RTO issues. The following table demonstrates the PUC’s involvement in the RTO stakeholder process.

Within the RTO and ISO stakeholder workgroups, maintaining reliability of the electric grid and regional transmission planning are critical issues. Driving this work is the transition of the electric generating resource mix from existing dispatchable resources to new intermittent resources as well as forecasted load growth (e.g., new data centers). Intermittent resources are generating resources that depend on the weather to produce energy (e.g., wind and solar) or may be energy limited (e.g., storage), whereas dispatchable resources can produce energy when called upon by the system operator to do so. Commissioners advocate for a cost-effective, orderly transition of the electric industry at RTO and ISO workgroup meetings, where regional transmission expansion plans, transmission cost allocation, resource accreditation, wholesale market reforms, and bulk power system reliability needs are a few of the hot topics.

  • In September, the PUC hosted a Regional Transmission Operator Information Session in the State Capitol in Pierre. Representatives from Southwest Power Pool, Midwest Independent System Operator, California ISO and the Midwest Reliability Organization provided updates on their organizations and answered questions.

  • In October, the Organization of MISO States held their 2025 OMS Annual Meeting in Sioux Falls. The meeting brought together leaders from OMS’ 17 member organizations from 15 states and the Canadian province of Manitoba. The meeting’s sessions focused on the energy sector’s rapid transformation highlighting topics like shifting technologies, evolving markets, changing policy and political landscapes and possible regulatory paths forward. Commissioner Nelson was instrumental in the planning effort.

PUBLIC OUTREACH AND CONSUMER ASSISTANCE

  • The PUC visited with more than 2,750 consumers about the purpose and services of the PUC at spring home shows in Sioux Falls and Rapid City and at the South Dakota State Fair.

  • The commission continued educating consumers about scam calls with the “Don’t Know? Don’t Answer!” informational campaign. The campaign informs consumers about scam calls, the tricks scam callers use to gain access to sensitive information or resources and provides tips on how to report scams and protect against their tactics.

GRAIN WAREHOUSE

  • Performed 480 inspections

  • The commission continued the “Ask an Inspector” promotional campaign at the South Dakota State Fair. The campaign encourages producers to contact the PUC’s grain warehouse staff with any questions about South Dakota’s grain industry and to report any concerns about the practices or financial solvency of grain businesses operating in South Dakota.

PIPELINE SAFETY

  • PUC staff completed 173.5 days of pipeline safety inspections.

  • The PUC hosted the South Dakota/North Dakota Pipeline Safety Operator Training in Sioux Falls for more than 140 members of the pipeline safety industry from both states. Participants attended presentations by experts discussing topics like gas leak detection, excavation damage, distribution integrity management, pipeline safety management systems, accident investigations and cybersecurity. The event also included an exhibitor showcase with 18 companies participating.

  • The commission recognized National Safe Digging Month in April and reminded South Dakotans to Call Before You Dig. Calling 811 before any excavation or digging project helps safeguard underground utilities, preserve vital services and protect against harm that can result from hitting buried infrastructure.

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