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Home My WebLink About2022 Oooguruk-Nuiqsut Oil Pool2rnn� us operaC�nng 2022 Annual Reservoir Surveillance Report Oooguruk-Nuigsut Oil Pool (ONOP) Oooguruk Field April 1, 2023 Table of Contents SUBJECT PAGE 1.0 Progress of the Enhanced Recovery Project.............................................................................1 2.0 Results and Analysis of Reservoir Pressure Surveys within the Pool..........................................4 3.0 Results and Analysis of Production and Injection Log Surveys, Tracer Surveys, Observation Well Surveys and Any Other Special Monitoring.......................................................................................4 4.0 Review of Pool Production Allocation Factors and Issues Over the Year....................................5 5.0 Reservoir Management Summary.......................................................................................... 6 ATTACHMENT A ONOP Well Location Map................................................................................... 8 ATTACHMENT B 2022 ONOP Voidage Balance by Month................................................................9 ATTACHMENT C ONOP Pressure Report, Form 10-412................................................................. 10 ATTACHMENT D ONOP Reservoir Pressure Map — December, 2022.............................................. 11 ATTACHMENT E ONOP Annual Reservoir Properties Report, Form 10-428..................................... 12 Eni Petroleum, Alaska 1.0 Progress of the Enhanced Recovery Project The Oooguruk Field (OF) is one of two Eni US Operating Co. Inc. (Eni) offshore -operated fields in Alaska. Three oil pools, the Torok, Kuparuk, and Nuiqsut, are currently under development within the OF. The development consists of an offshore man-made gravel island, the Oooguruk Drill site (ODS), located just east of the Colville River Delta in Harrison Bay. ODS production is delivered to the Oooguruk Tie-in Pad (OTP) via a buried subsea flowline bundle and onshore flowlines, metered, then transferred to Kuparuk River Unit (KRU) facilities, operated by ConocoPhillips Alaska, Inc. (CPA[), for final processing and transportation to the sales line. At the end of 2022, there were 28 active Oooguruk-Nuiqsut Oil Pool (ONOP) development wells, including 18 producer and ten injection wells. One producing well, ODSN-06 Nuiqsut, is shut-in as it is isolated in the ODSN-06 wellbore to allow production of the Kuparuk interval. Commingling is not currently allowed nor functional at this time. The locations of the ONOP, the existing and planned ONOP wells, the current OU, and Oooguruk Nuiqsut Participating Area (ONPA) are shown in Attachment A. During 2022, OF engineering performed an internal operations and maintenance assessment to ensure compliance with corporate requirements. Additionally, Eni's corporate operations team performed a cold -eye review of the Oooguruk plant to identify bottlenecks, efficiencies and production improvement opportunities. An internal corporate assessment was also performed to ensure compliance with internal procedures on safety and environmental critical elements. Engineering work commenced on an integrated model to connect the reservoir, wells and surface production equipment to facilitate production optimization. An engineering study for revamping the 2-phase separator also started. Operations included general maintenance and replacement of critical oil, water, and gas piping and valves. Additional field -wide maintenance was also performed, including mechanical integrity inspections of piping, tanks, pressure vessels and other safety systems. Routine maintenance was performed on the three power generation turbines and two gas injection compressors at OTP. Compressors A and B were inspected to identify potential design flaws and asset integrity improvements. Major overhauls were performed to Compressor B as well as Turbine C. In addition, cathodic protection inspections were completed on the sub -sea production flowline from ODS to OTP to ensure mechanical integrity of the pipelines. A detailed monitoring plan for injection system microbes was established with systematic biocide treatments conducted during 2022. Capital projects included eight (8) well work overs, 7 producers and 1 injector. Four (4) ESPs were installed in production wells. The ODS control room was relocated into the camp during the summer 2022, followed by a design study to relocate the OTP control room in 2024. Capital projects included the upgrade of the Fire and Gas software, mandatory tank and vessel inspections, lift/injection compressor PLC upgrade and module lifecycle upgrade. The ODS exterior camera system was upgraded to allow enhanced warning of nearby polar bears, Eni Petroleum, Alaska Page 1 seawater injection line pig trap upgrades and adding a corrosion coupon to the ODS subsea diesel flowline. A conversion from the existing Siemens PCS7 Distributed Control System (DCS) to Emerson DeltaV has been developed with detailed engineering study supporting implementation during the 2024 maintenance turnaround. Finally, a revamping of the Rig Support Complex (RSC), in order to support the Well work Over campaign and future drilling campaign was started and will be complete in 2023. Design and fabrication work continued with the OTP Partial Gas Processing project. Expected startup is December 2023. Similarly, the Electrical Power Sharing project continued with design and procurement, with startup scheduled for 2025. The Oooguruk development originally envisioned producing wells would ultimately utilize electrical submersible pump completions (ESPs) in order to maximize drawdown and minimize gas lift and the associated KRU and hydraulic back -out effects. Currently, the majority of the OF producing wells require gas lift to produce. The gas lift gas coupled with the OF formation gas significantly impacts the flowline pressure, reducing overall flowrates, and generates significant back -out cost at KRU, which is also primarily constrained by gas processing capacity. These constraints result in backing out KRU fluid production when high total gas oil ratio (TGOR, includes formation and lift gas) OF fluids enter the system. Because of the hydraulic effects and KRU back -out all OF wells cannot be produced concurrently using gas lift. In 2022, on average, 12 of the 22 available producing OF wells were on-line with TGOR ranking typically used to determine which wells to produce. As planned in 2022, rig mobilization and recommissioning of the Rig Support Complex (RSC) was completed, and Oooguruk rig activity was initiated in May 2022. Eight rig workover (RWO) interventions were completed in five ONOP wells (ODSN-06, ODSN-02, ODSN-31, ODSN-25, and ODSN-29) through December 2022.. Table 1 below, summarizes the ONOP RWO and rigless (RLWO) interventions completed in 2022. A RWO was initiated in the ODSN-10 well on December 28, 2022 to restore function of the subsurface safety valve, but it was not completed until January 20, 2023. Eni Petroleum, Alaska Page 2 Action # Well Name Well type Reservoir Action type Objectives/Description Completion Date 1 ODSN-01A OP Nuiqsut RLWO Coil fluff & stuff to 17,300' 21-Jan-22 2 ODSN-24 OP Nuiqsut RLWO Clear hydrate in tubing and return well to production 24-May-22 3 ODSN-17 OP Nuiqsut RLWO Repair SSSV and return well to production 1-Jun-22 4 ODSN-06i OP Nuiqsut RWO Up -hole recompletion in the Kuparuk 11-Jun-22 5 ODSN-06 OP Nuiqsut /Kuparuk RLWO Passport test 11-Jun-22 6 ODSN-02 OP Nuiqsut RLWO Pre-RWO Preparations 19-Jun-22 7 ODSN-17 Resume OP Nuiqsut RLWO Repair SSSV and return well to production 29-Jun-22 8 ODSN-02 OP Nuiqsut RWO Pull gas lift completion and run ESP 21-Jul-22 9 ODSN-02 OP Nuiqsut RLWO Passport test 21-Jul-22 10 ODSN-31 OP Nuiqsut RLWO Pre-RWO Preparations 29-Jul-22 11 ODSN-18 OP Nuiqsut RLWO Pull and replace plugged gas lift valve 9-Aug-22 12 ODSN-25 OP Nuiqsut RLWO Pre-RWO Operations 12-Aug-22 13 ODSN-31 OP Nuiqsut RWO Pull and Replace failed SSSV and install new ESP 19-Aug-22 14 ODSN-25 OP Nuiqsut RWO Passport test 9-Sep-22 15 ODSN-25 OP Nuiqsut RWO ESP Replacement 9-Sep-22 16 ODSN-31 OP Nuiqsut RWO Patch casing and run ESP 1-Oct-22 17 ODSN-19 WI Nuiqsut RLWO Passport test 6-Oct-22 18 ODSN-17 OP Nuiqsut RLWO Passport test 7-Oct-22 19 ODSN-18 OP Nuiqsut RLWO Passport test 8-Oct-22 20 ODSN-29 OP Kuparuk- Nuiqsut RWO Kuparuk isolation & Open Nuiqsut 22-Nov-22 21 ODSN-24 OP Nuiqsut RLWO Static pressure and temperature survey 27-Nov-22 22 ODSN-17 OP Nuiqsut RLWO Static pressure and temperature survey 29-Nov-22 23 ODSN-10 OP Nuiqsut RLWO Static pressure and temperature survey 30-Nov-22 24 ODSN-25 OP Nuiqsut RWO ESP Replacement 9-Dec-22 25 ODSN-31 OP Nuiqsut RWO Repair PVV and ESP electrical issue 17-Dec-22 26 ODSN-10 OP Nuiqsut RLWO Pull stuck SSSV and return to production 22-Dec-22 Table 1: 2022 ONOP Well Interventions As a result of the 2022 rig program and sustained water injection, OF oil production has increased 37% from 4,987 bopd in December 2021 to 6,825 bopd in December 2022. Water rates are up 20% from 3,053 bpd to 3,667 bpd, and total gas rates, formation plus lift gas, have decreased from 23 MMSCFPD to 17 MMSCFPD. However, the OF production network remains hydraulically constrained and only 13 of the 22 available wells were on-line on December 31, 2022. Annual average daily ONOP oil production for 2022 was 5,098 BOPD. Total oil production during 2022 was 1,860,641 barrels for a cumulative 35,810,250 barrels since field start-up in 2008. The 2022 annual average producing gas oil ratio (GOR) and watercut were 1,085 SCF/STBO and 30%, respectively. The December 2022 average GOR was 666 SCF/STBO and the watercut was 31%. Average annual daily water injection for 2022 was 12,619 bpd. Total water injection in 2022 was 4,606,101 barrels for a cumulative 35,154,851 barrels since the start of injection in 2009. The December 2022 average injection rate was 10,004 bpd. No gas injection occurred in 2022. Cumulative gas injection in the ONOP is 12,617 MMscf since the start of the project. The annual voidage replacement ratio averaged 92% for the year. The cumulative voidage replacement ratio is at 56%. Attachment B details the 2022 voidage balance for the ONOP. Eni Petroleum, Alaska Page 3 2.0 Results and Analysis of Reservoir Pressure Surveys within the Pool Fifteen pressure surveys recorded in 2022 were reported from twelve wells. The pressure survey results are summarized in the ONOP Pressure Report, Form 10-412 (See Attachment C). The ONOP Reservoir Pressure Map, Attachment D, depicts the estimated ONOP average pressures for December 2022 including all wells, both shut-in and on-line. The estimated average ONOP December 2022 reservoir pressure is 2,500 psi at 6,350 ft. TVDss. The 2022 average annual producing GOR was 1,085 SCF/STBO and in December 2022 the GOR averaged 666 SCF/STBO consistent with sustained and increasing water injection voidage replacement (See Attachment E, Nuigsut Annual Reservoir Properties Report Form 10-428). 3.0 Results and Analysis of Production and Injection Log Surveys, Tracer Surveys, Observation Well Surveys and Any Other Special Monitoring Reservoir surveillance is routinely conducted to monitor wells and reservoir performance and to recommend changes in operating conditions, perform rate allocations, propose optimization actions, address, and solve general issues. Historically well surveillance equipment was placed in the liners of seventeen Nuiqsut wells during the initial completions. The systems are in -place to assess production profiles and continuity along the lateral via target fluid tracers, which were monitored and analyzed by collecting surface fluid samples during restarts and over time. The tracers have been used to assess hydraulic connectivity along the laterals to evaluate the need for coil tubing interventions to clear any sand or debris blocking the flow path. For all wells the oil tracer components are no longer active. However, if a significant water breakthrough event occurs sampling to assess the water tracer response is planned. During unplanned 2022 well interventions pressure surveys were collected in the ODSN-10, ODSN-17 and ODSN-24 wells. Eni Petroleum, Alaska Page 4 4.0 Review of Pool Production Allocation Factors and Issues Over the Year Production from the Oooguruk-Torok Oil Pool (OTOP), Oooguruk-Kuparuk Oil Pool (OKOP) and Oooguruk-Nuiqsut Oil Pool (ONOP) is commingled at the surface into a common production line. Allocation between the pools is based on the ratio of total production for a pool to the total production for the Oooguruk Unit. The pool oil allocation factors for 2022 are: ONOP: 84.5% OKOP: 15.5% OTOP: 0.0% Theoretical production for individual wells for all pools is calculated on a daily basis. During 2021 wells were produced with chokes at 100% most of the time due to the capacity of the production line. Daily theoretical production for a well was calculated using the data from the most current well test and the amount of time a well was on production for a given day: Minutesprod„eed 1440Minut7 day xDailyRate(BOPD)We«tes, = TheoreticalDaily Production The daily allocation factor for the unit is calculated by dividing the actual total production for the day by the sum of the theoretical daily production for each individual well. Daily allocated production is assigned to each well by multiplying its theoretical daily production by the daily allocation factor. The average daily allocation factor for 2022 was 0.9301. Eni Petroleum, Alaska Page 5 5.0 Reservoir Management Summary The AOGCC issued pool rules under Conservation Orders No. 645A, 596 and 597 for the OTOP, OKOP and the ONOP, respectively. While there is no subsurface commingling, unitized substances produced from the three oil pools are commingled on the surface. Area injection orders (AIOs) authorizing the injection of fluids for enhanced oil recovery in the OTOP, OKOP, and ONOP reservoirs were issued by the AOGCC as AIO No. 37A, 33 and 34, respectively. Injection commenced into the ONOP in 2009. During 2022 the ONOP Under -Saturated Water -Alternating -Gas (US -WAG) reservoir management included maximizing voidage replacement, while minimizing known adverse injector to producer flow path connections and managing producing gas oil ratios by cycling producing wells on and off production where possible operationally. The current cumulative voidage replacement ratio is at 56%, which is consistent with ratio of injection wells to producing wells (17 producer and ten injection wells active) and the overall ONOP pattern layout. Attachment B details the 2022 annual and cumulative voidage balance for the ONOP. In general, producing wells in the more mature flood areas have seen GOR stabilization, stabilized or increased oil production, and some water breakthrough as expected, and also via unexpected connections which are being evaluated and monitored. With the consistent water injection and ample supply due to implementation of SWIS, ONOP flood throughput has increased reducing the overall GOR and increasing area pressures. Following the July 2019 water injection shut-in, the ONOP average monthly GOR peaked in September 2020 at 1,435 SCF/STBO from a low of 675 SCF/STBO in October 2019 and has since declined to 666 SCF/STBO in December 2022. Similarly, ONOP average monthly watercut decreased from 20% in August 2019 to 10% in January 2021 and has since increased to 31% in December 2022. Overall ONOP pressures have stabilized and in some areas are increasing. The central Kalubik fault block (Kalubik) currently has 11 wells, seven producers and four injectors. Two producers, ODSN-01A and ODSN-37, were produced consistently during 2022 with uptime greater than 75%. Production from four wells, ODSN-24 (7% uptime), ODSN-25 (32% uptime), ODSN-36 (40% uptime), and ODSN-42B (60% uptime), was limited due to facility constraints and to manage voidage replacement and producing GORs. The ODSN-31 well had very limited production (4% uptime) due to a failed SSSV in 2021 with two workovers completed in 2022, restoring production in December via an ESP recompletion. ODSN-25 was also recompleted with an ESP in September and again in December 2022. Kalubik 2022 average daily production was 1,373 BOPD with 492 BWPD (26% water cut) at a 1,420 SCF/STBO GOR. Water injection was sustained throughout 2022 in both ODSN-19 and ODSN-26 at moderate pressures to provide pressure support and improve recovery in offset producers while also minimizing known flow path connections. Injection in the central wells, ODSN-32 and ODSN-34, was sustained through August while monitoring for any connections (none are known to date), thus increasing cumulative VRR, and supporting central and up -dip Kalubik wells; injection into these wells was shut-in from August to December due to lower priority and limited area production at Eni Petroleum, Alaska Page 6 the time. The Kalubik 2022 annual average daily water injection rate was 3,169 BPD; gas was not injected during 2022. The southern Colville Delta and ERD fault block area (CD-ERD) currently has nine wells, six producers and three injectors. Two producers, ODSN-16 and ODSN-43 produced consistently during 2022 with greater than 98% uptime. Production from three wells, ODSN-10 (66% uptime), ODSN-18 (61% uptime), and ODSN-22 (73% uptime), was limited due to facility constraints and to manage voidage replacement and producing GORs. ODSN-17 has been shut-in since October 2021 due to a failed SSSV; several interventions were conducted in 2022 to repair the valve, but its function has not been restored; the well remains shut-in and secured. CD-ERD 2022 average daily production was 2,184 BOPD with 468 BWPD (18% watercut) at a 1,140 SCF/STBO GOR. Water injection was sustained throughout 2022 in ODSN-15 and ODSN-23; injection in ODSN-48 was shut-in from January to June due to a strong water flow patch connection impacting production in ODSN-22; the shut-in allowed ODSN-22 water production to clean-up and ODSN-48 injection has been sustained. The Colville Delta 2022 annual average daily water injection rate was 4,210 BPD; gas was not injected in the CD-ERD injectors during 2022. The Ivik fault block (Ivik) currently has eight wells, five producers and three injectors. Two producers, ODSN-02 and ODSN-28, were produced consistently during 2022 with 86% and 100% uptime, respectively. Production ODSN-04 was limited to 49% uptime due to a non-competitive TGOR on gas lift. As planned Kuparuk offtake was moved more distal from the ODSN-29 wellbore to the ODSN-06 wellbore which will improve recovery from both pools. Consequently, ODSN-06 Nuiqsut was shut-in in April to recomplete the wellbore in the Kuparuk; the Nuiqsut in the well is isolated and commingling is not currently allowed nor functional at this time. Concurrently, after isolating the Kuparuk in the ODSN-29 wellbore, the lower Nuiqsut completion was reopened and production restarted and sustained since November. Ivik 2022 average daily oil production was 1,541 BOPD with 1,242 BWPD (45% watercut) at a 707 SCF/STBO GOR. Water injection was sustained throughout 2022 in ODSN-03, ODSN-07, and ODSN-27 with periodic rate adjustments to manage voidage replacement and known water flow path connections during producer shut- ins. The Ivik 2022 annual average daily water injection rate was 5,241 BPD. Individual well and pattern surveillance data will continue to be collected to monitor performance and improve recovery. A simulation model has been maintained and updated to assist in reservoir development and flood management decisions in the ONOP. 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O 4-1 G1 L Gl Q O L a 0 w 4A _ a a) m m a From:Roby, David S (OGC) To:Carlisle, Samantha J (OGC); Guhl, Meredith D (OGC); AOGCC Reporting (CED sponsored) Subject:FW: Eni"s 2022 Oooguruk Reservoir Surveillance Reports Date:Monday, April 17, 2023 3:23:18 PM Eni has dropped the confidentiality request. Please add a copy of this email chain to the PDFs of the reports. Dave Roby (907)793-1232 From: Province Robert <Robert.Province@eni.com> Sent: Monday, April 17, 2023 2:55 PM To: Roby, David S (OGC) <dave.roby@alaska.gov> Subject: Eni's 2022 Oooguruk Reservoir Surveillance Reports Dave, Regarding Eni’s recently submitted 2022 Reservoir Surveillance Reports for both Nikaitchuq and Oooguruk Units, please disregard Eni’s request for confidentiality stated in our transmittal letter dated March 31, 2023. If you need an amended transmittal letter for the record, let me know. Please accept our apologies for this oversight. Thanks, Robert A. Province Manager – Land & Public Relations Eni US Operating Co. Inc (907) 865-3350- Office (907) 947-3793 – Cell Email: robert.province@eni.com From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Thursday, April 13, 2023 1:16 PM To: Province Robert <Robert.Province@eni.com> Subject: RE: [EXTERNAL] RE: Eni's 2022 Oooguruk Reservoir Surveillance Reports Hi Robert, No worries. Because you made a claim of confidentiality, one that we disagree with, we’re not going to make the documents available to the public until we resolve the issue. Waiting until early next week is no big deal but if it drags on too long we may take other steps, like scheduling a hearing on the matter. Regards, Dave Roby (907)793-1232 From: Province Robert <Robert.Province@eni.com> Sent: Thursday, April 13, 2023 12:53 PM To: Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL] RE: Eni's 2022 Oooguruk Reservoir Surveillance Reports Dave, Thank you for the helpful information below. I am suspecting early next week, to revoke Eni’s request for the RSRs be held Confidential. I will contact you as soon as I hear back from HQs. Again, thank you in advance for your patience in this regard. Robert A. Province Manager – Land & Public Relations Eni US Operating Co. Inc (907) 865-3350- Office (907) 947-3793 – Cell Email: robert.province@eni.com From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Wednesday, April 12, 2023 3:49 PM To: Province Robert <Robert.Province@eni.com> Subject: RE: [EXTERNAL] RE: Eni's 2022 Oooguruk Reservoir Surveillance Reports Hi Robert, Yes, but it’s a little convoluted. 20 AAC 25.517 requires and initial reservoir development plan and then annual updates to said plan, so submitting an annual plan is a regulatory requirement. However, that requirement is usually superseded, as it is in the case of Eni’s operations, when pool rules are issued that prescribe slightly different requirements for a reservoir surveillance report (for example, Rule 12 of CO 631 prescribes the rules for Nikaitchuq’s report). The pool rules are issued in accordance with 20 AAC 25.520 and thus the rules in the orders have the same effect (i.e. it is a requirement the operator has to follow and the AOGCC could take an enforcement action against an operator if they do not abide by the conditions of the rule) as if they were written directly in the regulations themselves. In reference to why we’re saying these reports should be public information, 20 AAC 25.537(a) states: The commission will routinely make available to the public, by means of records or reports, in its offices or elsewhere, or by means of regular publication, the following information: …(3) all reports and information required by this chapter [this refers to 20 AAC 25] for development and service wells,… So, since the reports are required by an order issued under the chapter it’s our position the reports should be public. Hope this helps. Regards, Dave Roby (907)793-1232 From: Province Robert <Robert.Province@eni.com> Sent: Wednesday, April 12, 2023 2:48 PM To: Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL] RE: Eni's 2022 Oooguruk Reservoir Surveillance Reports Dave, I probably won’t be able to get a final response to you until next week. Also, Headquarters had asked how AOGCC makes the request for these reports. It’s a regulatory requirement, correct? I am attempting to convince Headquarters to remove their confidentiality request. Eni has never requested confidentiality status on the RSRs. Robert A. Province Manager – Land & Public Relations Eni US Operating Co. Inc (907) 865-3350- Office (907) 947-3793 – Cell Email: robert.province@eni.com From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Monday, April 10, 2023 2:13 PM Security Warning: This email originated from outside of the organization. Do not click links or open attachments unless you have verified the sender’s email address and know the content is safe. To: Province Robert <Robert.Province@eni.com> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov>; Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: [EXTERNAL] RE: Eni's 2022 Oooguruk Reservoir Surveillance Reports Hi Robert, I haven’t heard anything back on the confidentiality issue. Have you had a chance to think about this? Regards, Dave Roby (907)793-1232 From: Roby, David S (OGC) Sent: Monday, April 3, 2023 2:47 PM To: Province Robert <Robert.Province@eni.com> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov>; Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: RE: Eni's 2022 Oooguruk Reservoir Surveillance Reports Hi Robert, I understand there’s been some back and forth this morning about additional submittals. What we need are Excel spreadsheet versions of the 10-412 reports that are attachment C in the ARSs and the 10-428 that is Attachment E in the reports to facilitate loading this information into our database. Attached is your submittal of the 412s from last year for reference. Also, on the Annual surveillance reports and the Polymer Injection project report on the cover letters you request that the reports be held confidential. Many moons ago you submitted ARSs marked as confidential and at that time you said that was done in error and Eni wasn’t seeking to have the reports held confidential (see attached email). Has Eni’s position on this matter changed? If so you will need to provide justification for the AOGCC to consider for why these documents should be held confidential. Generally speaking, information that the AOGCC requires to be submitted, as is the case for the ARSs and the polymer injection report since those were required by orders issued by the AOGCC, is considered public information unless it is entitled to confidentiality under some other provision of state or federal law. In which case the specific information that is entitled to confidentiality can be redacted from the report but the bulk of the report will be made available to the public. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Regards, Dave Roby (907)793-1232 From: Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov> Sent: Monday, April 3, 2023 12:08 PM To: Roby, David S (OGC) <dave.roby@alaska.gov>; Brooks, James S (OGC) <james.brooks@alaska.gov> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: FW: Eni's 2022 Oooguruk Reservoir Surveillance Reports From: Province Robert <Robert.Province@eni.com> Sent: Monday, April 3, 2023 12:05 PM To: Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov> Cc: Zuber Joshua <Joshua.Zuber@eni.com> Subject: Eni's 2022 Oooguruk Reservoir Surveillance Reports Sam, Attached please find the subject reports (digital copies) that I dropped off at AOGCC on Friday March 31st. Remainder of reports to follow in next email. Robert A. Province Manager – Land & Public Relations Eni US Operating Co. Inc (907) 865-3350- Office (907) 947-3793 – Cell Email: robert.province@eni.com ------------------------------------------------------------------------------------------------------------------------- ----------------------------------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/