# EDGAR Filing Document

**Accession Number:** 0001866175
**File Stem:** 0001193125-23-014843
**Filing Date:** 2023-1
**Character Count:** 90869
**Document Hash:** 6f3ab6b860c5942da6fb3c467be034e4
**Contains OCR:** False
**Source Format:** 

## Filing Content

## Filing Summary
**0001193125-23-014843.hdr.sgml**: 20230125

**ACCESSION NUMBER**: 0001193125-23-014843

**CONFORMED SUBMISSION TYPE**: 8-K

**PUBLIC DOCUMENT COUNT**: 24

**CONFORMED PERIOD OF REPORT**: 20230125

**ITEM INFORMATION**: Results of Operations and Financial Condition

**ITEM INFORMATION**: Regulation FD Disclosure

**ITEM INFORMATION**: Other Events

**ITEM INFORMATION**: Financial Statements and Exhibits

**FILED AS OF DATE**: 20230125

**DATE AS OF CHANGE**: 20230125

**FILER**: 

**COMPANY DATA:**
- **COMPANY CONFORMED NAME:** Crescent Energy Co
- **CENTRAL INDEX KEY:** 0001866175
- **STANDARD INDUSTRIAL CLASSIFICATION:** CRUDE PETROLEUM & NATURAL GAS [1311]
- **IRS NUMBER:** 000000000
- **STATE OF INCORPORATION:** DE
- **FISCAL YEAR END:** 1231

**FILING VALUES:**
- **FORM TYPE:** 8-K
- **SEC ACT:** 1934 Act
- **SEC FILE NUMBER:** 001-41132
- **FILM NUMBER:** 23549928

**BUSINESS ADDRESS:**
- **STREET 1:** 600 TRAVIS STREET
- **STREET 2:** SUITE 7200
- **CITY:** HOUSTON
- **STATE:** TX
- **ZIP:** 77002
- **BUSINESS PHONE:** (713) 481-7782

**MAIL ADDRESS:**
- **STREET 1:** 600 TRAVIS STREET
- **STREET 2:** SUITE 7200
- **CITY:** HOUSTON
- **STATE:** TX
- **ZIP:** 77002

**FORMER COMPANY:**
- **FORMER CONFORMED NAME:** IE PubCo Inc.
- **DATE OF NAME CHANGE:** 20210607

?xml version="1.0" encoding="utf-8" ? 8-K

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### UNITED STATES

### SECURITIES AND EXCHANGE COMMISSION

#### Washington, D.C. 20549

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### FORM 8-K

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#### CURRENT REPORT

#### PURSUANT TO SECTION 13 OR 15(D)

#### OF THE SECURITIES EXCHANGE ACT OF 1934

#### Date of report (Date of earliest event reported): January 25, 2023

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## Crescent Energy Company

#### (Exact Name of Registrant as Specified in Charter)

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---

| | | |
|:---|:---|:---|
| **Delaware** | **001-41132** | **87-1133610** |
| **(State or Other Jurisdiction**<br> **of Incorporation)** | **(Commission**<br> **File Number)** | **(I.R.S. Employer**<br> **Identification Number)** |

---

---

| | |
|:---|:---|
| **600 Travis Street, Suite 7200**<br> **Houston, Texas** | **77002** |
| **(Address of Principal Executive Offices)** | **(Zip Code)** |

---

(713) 337-4600

#### (Registrant's Telephone Number, Including Area Code)

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Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

☐ Written communication pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

☐ Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

☐ Pre-commencement communication pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

☐ Pre-commencement communication pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Securities registered pursuant to Section 12(b) of the Act:

---

| | | |
|:---|:---|:---|
| **Title of each class** | **Trading**<br> **Symbol(s)** | **Name of each exchange**<br> **on which registered** |
| Class A Common Stock, par value $0.0001 per share | CRGY | The New York Stock Exchange |

---

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§ 230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§ 240.12b-2 of this chapter).

Emerging growth company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

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| | |
|:---|:---|
| **Item 2.02.** | **Results of Operations and Financial Condition.**  |

---

On January 25, 2023, in connection with the Notes Offering (as defined below), Crescent Energy Company (NYSE: CRGY) ("CRGY" or "our," "us," or "we") provided certain updated disclosures to potential investors, the relevant excerpts of which are set forth below.

#### Certain preliminary data for Q4 2022
As of the date of this current report, we have not finalized our financial and operational results for the year ended December 31, 2022. However, based on preliminary information, we estimate that, for the year ended December 31, 2022, our production ranged from 137 to 139 thousand barrels of oil equivalent per day ("MBoe/d").

This preliminary estimate is derived from our internal records and is based on the most current information available to management. This estimate is preliminary and inherently uncertain. Our normal reporting processes with respect to the foregoing preliminary estimate have not been fully completed. Our independent auditors have not completed an audit or review of such preliminary estimate or of any other data as of, or for a period ended, December 31, 2022 included in this Current Report. During the course of our and our auditors' review on this preliminary estimate and any other such data, we could identify items that would require us to make adjustments and that could affect our final results. Any such adjustments could be material. This preliminary estimate should not be viewed as indicative of our financial condition or results as of or for any future period. Actual results could differ from the estimates, trends and expectations discussed herein, and such differences could be material.

In addition, the information contained in Item 8.01 of this Current Report is incorporated into this Item 2.02 by reference.

The information in this Item 2.02 shall not be deemed to be "filed" for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), or otherwise subject to the liabilities of that section, and is not incorporated by reference into any filing under the Securities Act of 1933, as amended (the "Securities Act"), or the Exchange Act.

---

| | |
|:---|:---|
| **Item 7.01.** | **Regulation FD Disclosure.**  |

---

On January 25, 2023, Crescent Energy Finance LLC ("CE Finance"), a subsidiary of CRGY, issued a news release announcing that, subject to market conditions, CE Finance intends to offer (the "Notes Offering") for sale in a private placement pursuant to Rule 144A and Regulation S under the Securities Act, to eligible purchasers $400 million aggregate principal amount of Senior Notes due 2028. A copy of the news release is attached hereto as Exhibit 99.1 and incorporated herein by reference.

In addition, the information contained in Item 2.02 and Item 8.01 of this Current Report is incorporated into this Item 7.01 by reference.

The information contained in this Item 7.01, including Exhibit 99.1, shall not be deemed to be "filed" for purposes of Section 18 of the Exchange Act, or otherwise subject to the liabilities of that section, and is not incorporated by reference into any filing under the Securities Act, or the Exchange Act.

---

| | |
|:---|:---|
| **Item 8.01** | **Other Events.**  |

---

On January 25, 2023, in connection with the Notes Offering, CRGY provided certain updated disclosures to potential investors, the relevant excerpts of which are set forth below in substantially the form in which they were provided in the Notes Offering.

\*\*\*\*\*\*

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Our free cash flow-focused portfolio includes a balanced set of oil and natural gas assets in proven onshore U.S. basins with substantial existing production, a low decline rate and an acreage position that is 96% held by production.

\*\*\*\*\*\*

Based on forecasts used in our reserve report, our provided developed producing ("PDP") reserves as of December 31, 2022 have estimated average five-year and ten-year annual decline rates of approximately 13% and 10%, respectively, and an estimated 2023 PDP decline rate of 22%. The relatively higher decline rate in 2023 is due primarily to the high initial production profiles of certain more recently drilled PDP wells acquired in the Uinta Acquisition (as defined below), which we expect to decrease over time as wellbore pressure gradually declines and stabilizes. As a result of this overall low decline profile, we require relatively minimal capital expenditures to maintain our production and cash flows. Our properties located in the Eagle Ford, the Rockies and Barnett represent approximately 84% of our proved reserves as of December 31, 2022, and provide us with diversification from both a regional location and commodity price perspective, which provides us certain downside protection as it relates to commodity-specific pressures, isolated infrastructure constraints or severe weather events. The table below illustrates the aggregate reserve volumes and weighted average decline profiles associated with our proved assets as of December 31, 2022.

---

| | | | |
|:---|:---|:---|:---|
| **Operating Area** | **Net Proved<br>Reserves (1)** | **% Oil &<br>Liquids (1)** | **Net PD<br>Reserves (1)** |
|  | **(MMBoe)** | | **(MMBoe)** |
|  Eagle Ford | 147 | 81% | 79 |
|  Rockies | 222 | 53% | 192 |
|  Barnett | 111 | 20% | 111 |
|  Other (2) | 94 | 67% | 78 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Total | 573 | 56% | 460 |

---

------

(1) Our reserves were determined using average first-day-of-the-month prices for the prior 12 months in accordance with guidance from the U.S. Securities and Exchange Commission (the "SEC"). For oil and natural gas liquids ("NGL") volumes, the average West Texas Intermediate ("WTI") posted price of $93.67 per barrel as of December 31, 2022, was adjusted for items such as gravity, quality, local conditions, gathering, transportation fees and distance from market. For natural gas volumes, the average Henry Hub Index spot price of $6.36 per one million British thermal unit ("MMBtu") as of December 31, 2022, was similarly adjusted for items such as quality, local conditions, gathering, transportation fees and distance from market. All prices are held constant throughout the lives of the properties. The average adjusted product prices over the remaining lives of the properties are $89.87 per barrel of oil, $5.80 per 1,000 cubic feet ("Mcf") of natural gas and $37.98 per barrel of NGLs.

(2) Includes working interest properties located in Mid-Con, California, Permian as well as diversified mineral and royalty interests.

\*\*\*\*\*\*

As of December 31, 2022, we have identified 247 net locations as proved undeveloped reserves ("PUD") drilling locations as of December 31, 2022, representing approximately $1.7 billion of reinvestment potential.

\*\*\*\*\*\*

As of December 31, 2022, our derivative portfolio had an aggregate notional value of approximately $1.4 billion. We determine the fair value of our oil and natural gas commodity derivatives using valuation techniques that utilize market quotes and pricing analysis. Inputs include publicly available prices and forward price curves generated from a compilation of data gathered from third parties.

------

The following table details our net volume positions by commodity as of December 31, 2022.

---

| | | | |
|:---|:---|:---|:---|
| **Production Period** | **Volumes** | **Weighted<br>Average** | **Fair Value** |
|  | **(in thousands)** | | **(in thousands)** |
|  Crude oil swaps (Bbls): |  |  |  |
|  WTI |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; 2023 | 9710 | $60.00 | $(180441) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; 2024 | 5721 | 63.82 | (54455) |
|  Brent |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; 2023 | 527 | 52.52 | (15690) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; 2024 | 276 | 68.65 | (2536) |
|  Crude oil collars – WTI (Bbls): |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; 2023 | 1155 | 48.68- 57.87 | (24467) |
|  Natural gas swaps (MMBtu): |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; 2023 | 62248 | 2.73 | (92657) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; 2024 | 9604 | 4.14 | (1139) |
|  NGL swaps (Bbls): |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; 2023 | 1379 | 40.80 | 15710 |
|  Crude oil basis swaps (Bbls): |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; 2023 | 2461 | 1.15 | 23 |
|  Natural gas basis swaps (MMBtu): |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; 2023 | 8202 | (0.43) | 980 |
|  Calendar Month Average roll swaps (Bbls): |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; 2023 | 2736 | 0.05 | (896) |
|  Natural gas collars (MMBtu): |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; 2023 | 550 | 2.63- 3.01 | (659) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; 2024 | 18300 | 3.38- 4.56 | (5607) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Total |  |  | $(361834) |

---

\*\*\*\*\*\*

#### Summary reserve data based on SEC Pricing
The following table provides our historical reserves, the pre-tax undiscounted present value of such reserves ("PV-0") and the pre-tax present value of such reserves discounted at ten percent ("PV-10") as of December 31, 2022, in each case prepared in accordance with SEC Pricing. SEC Pricing means the price per barrel ("Bbl") for oil or per MMBtu for natural gas as calculated from the unweighted arithmetic average first day of the month prices for the prior 12 months, as adjusted by lease for quality, transportation fees, geographical differentials, marketing bonuses or deductions and other factors affecting the price received at the wellhead. The reserve estimates presented in the tables below are based primarily on a reserve report prepared by Ryder Scott Company, LP ("Ryder Scott"). In preparing its report, Ryder Scott evaluated properties representing approximately 97% of our PV-10 and 98% of our total proved reserves as of December 31, 2022. Our internal technical staff evaluated the remaining properties.

---

| | |
|:---|:---|
|  | **As of<br>December 31,<br>2022 (1)** |
|  **Net Proved Reserves:** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Oil (MBbls) | 243082 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Natural gas (MMcf) | 1506535 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; NGLs (MBbls) | 78621 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Total Proved Reserves (MBoe) | 572793 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; PV-0 (millions) (2) | $17170 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; PV-10 (millions) (2) | $9602 |
|  **Net Proved Developed Reserves:** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Oil (MBbls) | 160113 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Natural gas (MMcf) | 1398770 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; NGLs (MBbls) | 66803 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Total Proved Developed Reserves (MBoe) | 460046 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; PV-0 (millions) (2) | $12330 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; PV-10 (millions) (2) | $7132 |
|  **Net Proved Undeveloped Reserves:** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Oil (MBbls) | 82969 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Natural gas (MMcf) | 107765 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; NGLs (MBbls) | 11818 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Total Proved Undeveloped Reserves (MBoe) | 112747 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; PV-0 (millions) (2) | $4840 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; PV-10 (millions) (2) | $2470 |

---

------

(1) Our reserves, PV-0 and PV-10 were determined using SEC Pricing. For oil and NGL volumes, the average WTI posted price of $93.67 per barrel as of December 31, 2022, was adjusted for items such as gravity, quality, local conditions, gathering, transportation fees and distance from market. For natural gas volumes, the average Henry Hub Index spot price of $6.36 per MMBtu as of December 31, 2022, was similarly adjusted for items such as quality, local conditions, gathering, transportation fees and distance from market. All prices are held constant throughout the lives of the properties. The average adjusted product prices over the remaining lives of the properties are $89.87 per barrel of oil, $5.80 per Mcf of natural gas and $37.98 per barrel of NGLs as of December 31, 2022. As of December 31, 2022, approximately $3,452 million, $3,564 million, $911 million and $1,674 million of the net proved PV-10 shown above, and approximately $1,907 million, $2,902 million, $911 million and $1,412 million of the net proved developed PV-10 shown above, relate to properties in the Eagle Ford, Rockies, Barnett and other operating areas, respectively.

(2) Present value (discounted at PV-0 and PV-10) is not a financial measure calculated in accordance with GAAP because it does not include the effects of income taxes on future net revenues. Neither PV-0 nor PV-10 represent an estimate of the fair market value of our oil and natural gas properties. Our PV-0 measurement does not provide a discount rate to estimated future cash flows. PV-0 therefore does not reflect the risk associated with future cash flow projections like PV-10 does. PV-0 should therefore only be evaluated in connection with an evaluation of our PV-10 of discounted future net cash flows. We believe that the presentation of PV-0 and PV-10 is relevant and useful to our investors about the future net cash flows of our reserves in the absence of a comparable measure such as standardized measure. We and others in our industry use PV-0 and PV-10 as a measure to compare the relative size and value of proved reserves held by companies without regard to the specific tax characteristics of such entities. Investors should be cautioned that neither of PV-0 and PV-10 represent an estimate of the fair market value of our proved reserves. The most directly comparable GAAP financial measure is standardized measure of discounted future net cash flows. Our standardized measure includes the effects of income taxes on future net revenues; however, neither such income tax effects nor such standardized measure is presented in this Current Report on Form 8-K, as certain tax estimates necessary for purposes of calculating such measures are unavailable to management as of the date hereof and a reconciliation thereto would not be available without unreasonable efforts.

#### Summary reserve data based on NYMEX pricing
The following table provides our historical reserves, PV-0 and PV-10 as of December 31, 2022 using NYMEX pricing. We have included this reserve sensitivity in order to provide an additional method of presentation of the fair value of our assets and the cash flows that we expect to generate from those assets based on the market's forward-looking pricing expectations as of December 31, 2022. The historical 12-month pricing average does not reflect the oil and natural gas futures. We believe that the use of forward prices provides investors with additional useful information about our reserves, as the forward prices are based on the market's forward-looking expectations of oil and natural gas prices as of a certain date, although we caution investors that this information should be viewed as a helpful alternative, not a substitute, for the data presented based on SEC Pricing. In addition, we believe strip pricing provides relevant and useful information because it is widely used by investors in our industry as a basis for comparing the relative size and value of our proved reserves to our peers and in particular addresses the impact of differentials compared with our peers. Our estimated historical reserves, PV-0 and PV-10 based on NYMEX pricing were otherwise prepared on the same basis as our estimations based on SEC Pricing reserves for the comparable period. Reserve estimates using NYMEX pricing are calculated using the internal systems of our management and have not been prepared or audited by an independent, third-party reserve engineer, but otherwise contain the same parameters, except for price and minor system differences.

---

| | |
|:---|:---|
|  | **As of<br>December 31,<br>2022 (1)** |
|  **Net Proved Reserves:** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Oil (MBbls) | 219499 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Natural gas (MMcf) | 1380510 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; NGLs (MBbls) | 70605 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Total Proved Reserves (MBoe) | 520189 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; PV-0 (millions) (2) | $8609 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; PV-10 (millions) (2) | $5315 |
|  **Net Proved Developed Reserves:** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Oil (MBbls) | 138501 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Natural gas (MMcf) | 1275631 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; NGLs (MBbls) | 59090 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Total Proved Developed Reserves (MBoe) | 410196 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; PV-0 (millions) (2) | $6050 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; PV-10 (millions) (2) | $4062 |
|  **Net Proved Undeveloped Reserves:** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Oil (MBbls) | 80998 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Natural gas (MMcf) | 104879 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; NGLs (MBbls) | 11515 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Total Proved Undeveloped Reserves (MBoe) | 109993 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; PV-0 (millions) (2) | $2558 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; PV-10 (millions) (2) | $1252 |

---

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(1) Our NYMEX reserves, PV-0 and PV-10 were determined using NYMEX pricing, without giving effect to derivative transactions and were calculated based on settlement prices to better reflect the market expectations as of that date, as adjusted for our estimates of quality, transportation fees, and market differentials. The NYMEX reserves calculations are based on NYMEX pricing at closing on December 31, 2022 for oil and natural gas. The average adjusted product prices over the remaining lives of the properties are $64.35 per barrel of oil, $3.94 per Mcf of natural gas and $27.31 per barrel of NGLs as of December 31, 2022. We believe that the use of forward prices provides investors with additional useful information about our reserves, as the forward prices are based on the market's forward-looking expectations of oil and natural gas prices as of a certain date, although we caution investors that this information should be viewed as a helpful alternative, not as a substitute, for the data presented based on SEC Pricing. As of December 31, 2022, approximately $2,003 million, $1,897 million, $455 million and $960 million of the net proved PV-10 shown above, and approximately $1,208 million, $1,545 million, $455 million and $855 million of the net proved developed PV-10 shown above, relate to properties in the Eagle Ford, Rockies, Barnett and other operating areas, respectively.

(2) Present value (discounted at PV-0 and PV-10) is not a financial measure calculated in accordance with GAAP because it does not include the effects of income taxes on future net revenues. Neither PV-0 nor PV-10 represent an estimate of the fair market value of our oil and natural gas properties. Our PV-0 measurement does not provide a discount rate to estimated future cash flows. PV-0 therefore does not reflect the risk associated with future cash flow projections like PV-10 does. PV-0 should therefore only be evaluated in connection with an evaluation of our PV-10 of discounted future net cash flows. We believe that the presentation of PV-0 and PV-10 is relevant and useful to our investors about the future net cash flows of our reserves in the absence of a comparable measure such as standardized measure. We and others in our industry use PV-0 and PV-10 as a measure to compare the relative size and value of proved reserves held by companies without regard to the specific tax characteristics of such entities. Investors should be cautioned that neither of PV-0 and PV-10 represent an estimate of the fair market value of our proved reserves. The most directly comparable GAAP financial measure is standardized measure of discounted future net cash flows. Our standardized measure includes the effects of income taxes on future net revenues; however, neither such income tax effects nor such standardized measure is presented in this Current Report on Form 8-K, as certain tax estimates necessary for purposes of calculating such measures are unavailable to management as of the date hereof and a reconciliation thereto would not be available without unreasonable efforts. GAAP does not prescribe any corresponding measure for PV-10 of reserves based on pricing other than SEC Pricing. As a result, it is not practicable for us to reconcile our PV-10 using NYMEX pricing to standardized measure as determined in accordance with GAAP.

\*\*\*\*\*\*

As of December 31, 2022, we had $559.0 million in outstanding borrowings under our revolving credit facility and no cash and cash equivalents.

\*\*\*\*\*\*

This Item 8.01 incorporates by reference the reserve report prepared by Ryder Scott Company, our independent reserve engineers, filed as Exhibit 99.2 herewith.

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| | |
|:---|:---|
| **Item 9.01** | **Financial Statements and Exhibits.**  |

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&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(d)&nbsp;&nbsp;&nbsp;&nbsp;Exhibits.

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| | |
|:---|:---|
| **Exhibit** | **Description** |
| 23.1 | [Consent of Ryder Scott Company, LP.](d452425dex231.htm) |
| 99.1 | [Press Release, dated January 25, 2023.](d452425dex991.htm) |
| 99.2 | [Report of Ryder Scott Company, LP.](d452425dex992.htm) |
| 104 | Cover Page Interactive Data File (embedded within the Inline XBRL document). |

---

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SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, CRGY has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

Date: January 25, 2023

---

| | |
|:---|:---|
| **CRESCENT ENERGY COMPANY** | **CRESCENT ENERGY COMPANY** |
| By: | /s/ Bo Shi |
| Name: | Bo Shi |
| Title: | General Counsel |

---

## Exhibit 23.1

**Exhibit 23.1**![LOGO](g452425g0124022735604.jpg) ![LOGO](g452425g0124022735901.jpg)

TBPELS REGISTERED ENGINEERING FIRM F-1580 FAX (713) 651-0849 <br> 1100 LOUISIANA SUITE 4600 HOUSTON, TEXAS 77002-5294 TELEPHONE (713) 651-9191

**Consent of Independent Petroleum Engineers** 

To the Board of Directors

Crescent Energy Company:

We have issued our report dated January 20, 2023 on estimates of oil, natural gas and NGL reserves estimates and forecasts of economics as of December 31, 2022. As independent oil and gas consultants, we hereby consent to the inclusion of our report and the information contained therein included in or made part of this Current Report on Form 8-K of Crescent Energy Company. Furthermore, we hereby consent to the incorporation by reference in that certain (i) Registration Statement on Form S-3 (File No. 333-269152), as may be amended from time to time, as originally filed with the U.S. Securities and Exchange Commission (the "Commission") on January 6, 2023, of the report and (ii) Registration Statement on Form S-8 (File No. 333-261604), as may be amended from time to time, as originally filed with the Commission on December 10, 2021, of the report.

---

| |
|:---|
| /s/ Ryder Scott Company, L.P. |
| **RYDER SCOTT COMPANY, L.P.** |
| TBPELS Firm Registration No. F-1580 |

---

Houston, Texas

January 25, 2023

SUITE 2800, 350 7TH AVENUE, S.W. CALGARY, ALBERTA T2P 3N9 TEL (403) 262-2799 <br> 633 17TH STREET, SUITE 1700 DENVER, COLORADO 80202 TEL (303) 339-8110

## Exhibit 99.1

**Exhibit 99.1**![LOGO](g452425g02p66.jpg)

**Crescent Energy Announces Offering of $400 Million Private Placement of Senior Notes Due 2028** 

HOUSTON, TX – (January 25, 2023) – Crescent Energy Company (NYSE: CRGY) ("we" or "our") announced today that, subject to market conditions, its indirect subsidiary Crescent Energy Finance LLC (the "Issuer") intends to offer for sale in a private placement pursuant to Rule 144A and Regulation S under the Securities Act of 1933, as amended (the "Securities Act"), to eligible purchasers $400 million aggregate principal amount of Senior Notes due 2028 (the "Notes"). The Notes will be guaranteed on a senior unsecured basis by all of the Issuer's subsidiaries that guarantee the Issuer's existing notes and the indebtedness under its revolving credit facility. The Issuer intends to use the net proceeds from this offering to repay a portion of the amounts outstanding under its revolving credit facility.

The Notes and the related guarantees have not been registered under the Securities Act, or any state securities laws, and, unless so registered, the Notes and the guarantees may not be offered or sold in the United States except pursuant to an exemption from, or in a transaction not subject to, the registration requirements of the Securities Act and applicable state securities laws. The Issuer plans to offer and sell the Notes only to persons reasonably believed to be qualified institutional buyers pursuant to Rule 144A under the Securities Act and to persons outside the United States pursuant to Regulation S under the Securities Act.

This communication shall not constitute an offer to sell, or the solicitation of an offer to buy, the securities described herein, nor shall there be any sale of these securities in any state or jurisdiction in which such offer, solicitation or sale would be unlawful prior to registration or qualification under the securities laws of any such state or jurisdiction.

**About Crescent Energy Company** 

Crescent Energy Company is a U.S. independent energy company with a portfolio of assets in basins across the lower 48 states.

**Cautionary Statement Regarding Forward-Looking Information** 

This communication contains forward-looking statements within the meaning of Section 27A of the Securities Act, and Section 21E of the Securities Exchange Act of 1934, as amended. These statements are based on current expectations. The words and phrases "should", "could", "may", "will", "believe", "think", "plan", "intend", "expect", "potential", "possible", "anticipate", "estimate", "forecast", "view", "efforts", "target", "goal" and similar expressions identify forward-looking statements and express our expectations about future events. This communication includes statements regarding this private placement and the use of proceeds therefrom that may contain forward-looking statements within the meaning of federal securities laws. We believe that our expectations are based on reasonable assumptions; however, no assurance can be given that such expectations will prove to be correct. A number of factors could cause actual results to differ materially from the expectations, anticipated results or other forward-looking information expressed in this communication, including liquidity and financial market conditions, including rising interest rates and associated policies of the U.S. Federal Reserve, commodity price volatility due to ongoing or new global conflicts such as the ongoing conflict in the Ukraine, adverse market conditions, governmental regulations, including the impact of the Inflation Reduction Act of 2022, and the impact of world health events such as the ongoing COVID-19 pandemic. All statements, other than statements of historical facts, included in this communication that address activities, events or developments that we expect, believe or anticipate will or may occur in the future are forward-looking statements. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond our control. Consequently, actual future results could differ materially from our expectations due to a number of factors, including, but not limited to, those items identified as such in the most recent Annual Report on Form 10-K and any subsequently filed Quarterly Reports on Form 10-Q and the risk factors described thereunder, filed by Crescent Energy Company with the U.S. Securities and Exchange Commission.

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Many of such risks, uncertainties and assumptions are beyond our ability to control or predict. Because of these risks, uncertainties and assumptions, you should not place undue reliance on these forward-looking statements. We do not give any assurance (1) that we will achieve our expectations or (2) concerning any result or the timing thereof.

All subsequent written and oral forward-looking statements concerning this offering, the use of proceeds therefrom, Crescent Energy Company and the Issuer or other matters and attributable thereto or to any person acting on their behalf are expressly qualified in their entirety by the cautionary statements above. We assume no duty to update or revise their respective forward-looking statements based on new information, future events or otherwise.

## Exhibit 99.2

**Exhibit 99.2** 

**CRESCENT ENERGY COMPANY** 

**Estimated** 

**Future Reserves and Income** 

**Attributable to Certain** 

**Leasehold and Royalty Interests** 

**SEC Parameters** 

**As of** 

**December 31, 2022** 

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| ![LOGO](g452425dsp011a.jpg) | /s/ Larry P. Connor, P.E.<br> Larry P. Connor, P.E.<br> TBPELS License No. 58639<br> Executive Vice President | /s/ Stephen E. Garner, P.E.<br> Stephen E. Garner, P.E.<br> TBPELS License No. 100578<br> Managing Senior Vice President | ![LOGO](g452425dsp011c.jpg) |

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| /s/ Timothy W. Smith, P.E.<br> Timothy W. Smith, P.E.<br> TBPELS License No. 70195<br> Managing Senior Vice President<br>**RYDER SCOTT COMPANY, L.P.**<br> TBPELS Firm Registration No. F-1580 | ![LOGO](g452425dsp011b.jpg) |

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RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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| ![LOGO](g452425dsp02a.jpg) | <br> ![LOGO](g452425dsp02b.jpg) <br> TBPELS REGISTERED ENGINEERING FIRM F-1580 | <br> ![LOGO](g452425dsp02b.jpg) <br> TBPELS REGISTERED ENGINEERING FIRM F-1580 | FAX (713) 651-0849 |
|  | 1100 LOUISIANA SUITE 4600 | HOUSTON, TEXAS 77002-5294 | TELEPHONE (713) 651-9191 |
|  |  | January 20, 2023 |  |

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Brian Periman

Director, Corporate Reserves

Crescent Energy Company

600 Travis Street, Suite 7200

Houston, Texas 77002

Dear Mr. Periman:

At your request, Ryder Scott Company, L.P. (Ryder Scott) has prepared an estimate of the proved reserves, future production, and income attributable to certain leasehold and royalty of Crescent Energy Company (Crescent) as of December 31, 2022. The subject properties are located in the Eagle Ford, Barnett, Midcontinent, Rockies, Permian and other producing areas in the lower 48 United States. The reserves and income data were estimated based on the definitions and disclosure guidelines of the United States Securities and Exchange Commission (SEC) contained in Title 17, Code of Federal Regulations, Modernization of Oil and Gas Reporting, Final Rule released January 14, 2009 in the Federal Register (SEC regulations). Our third party study, completed on January 20, 2023 and presented herein, was prepared for public disclosure by Crescent in filings made with the SEC in accordance with the disclosure requirements set forth in the SEC regulations.

The properties evaluated by Ryder Scott account for a portion of Crescent's total net proved liquid hydrocarbon and gas reserves as of December 31, 2022. Based on information provided by Crescent, the third party estimate conducted by Ryder Scott addresses approximately 98 percent of the total proved net reserves of Crescent on a barrel of oil equivalent, BOE basis as of December 31, 2022.

The estimated reserves and future net income amounts presented in this report, as of December 31, 2022 are related to hydrocarbon prices. The hydrocarbon prices used in the preparation of this report are based on the average prices during the 12-month period prior to the "as of date" of this report, determined as the unweighted arithmetic averages of the prices in effect on the first-day-of-the-month for each month within such period, unless prices were defined by contractual arrangements, as required by the SEC regulations. Actual future prices may vary considerably from the prices required by SEC regulations. The reserves volumes and the income attributable thereto have a direct relationship to the hydrocarbon prices actually received; therefore, volumes of reserves actually recovered and the amounts of income actually received may differ significantly from the estimated quantities presented in this report. The results of this study are summarized as follows.

SUITE 2800, 350 7TH AVENUE, S.W. CALGARY, ALBERTA T2P 3N9 TEL (403) 262-2799 <br> 633 17TH STREET, SUITE 1700 DENVER, COLORADO 80202 TEL (303) 339-8110

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Crescent Energy Company

January 20, 2023

**SEC PARAMETERS** 

Estimated Net Reserves and Income Data

Certain Leasehold and Royalty Interests of

**Crescent Energy Company**

As of December 31, 2022

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| | | | | |
|:---|:---|:---|:---|:---|
|  | Proved | Proved | Proved | Proved |
|  | Developed | Developed | | |
|  | Producing\* | Non-Producing |<br>Undeveloped | Total<br>Proved |
|  ***<u>Net Reserves</u>*** |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Oil/Condensate – Mbbl | 156423 | 1608 | 82969 | 241000 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Plant Products – Mbbl | 64606 | 117 | 11818 | 76541 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Gas – MMcf | 1358965 | 850 | 107765 | 1467580 |
|  ***<u>Income Data ($M)</u>*** |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Future Gross Revenue | $23227274 | $164079 | $8007762 | $31399115 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Deductions | 11466911 | 59001 | 3167774 | 14693686 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Future Net Income (FNI) | $11760363 | $105078 | $4839988 | $16705429 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Discounted FNI @ 10% | $6840474 | $43514 | $2469762 | $9353750 |

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*\** *The producing category includes a producing property in the Pine Tree Field that is under waterflood operations but has not yet recorded response. The reserves associated with this property are 897 Mbbl oil and represent 32,788 M$ discounted future net income at 10%.* 

Liquid hydrocarbons are expressed in standard 42 U.S. gallon barrels and shown herein as thousands of barrels (Mbbl). All gas volumes are reported on an "as sold basis" expressed in millions of cubic feet (MMcf) at the official temperature and pressure bases of the areas in which the gas reserves are located. In this report, the revenues, deductions, and income data are expressed as thousands of U.S. dollars ($M).

The estimates of the reserves, future production, and income attributable to properties in this report were prepared using the economic software package ARIESTM Petroleum Economics and Reserves Software, a copyrighted program of Halliburton. The program was used at the request of Crescent. Ryder Scott has found this program to be generally acceptable, but notes that certain summaries and calculations may vary due to rounding and may not exactly match the sum of the properties being summarized. Furthermore, one line economic summaries may vary slightly from the more detailed cash flow projections of the same properties, also due to rounding. The rounding differences are not material.

The future gross revenue includes "Other" revenue representing adjustments to lease ownership of certain leases in the Brea Canyon, 100 Acre and Olinda Fee areas located in California when the net revenue interest owned varies according to a base production volume specified within the lease agreement, and is after the deduction of production taxes. The deductions incorporate the normal direct costs of operating the wells, gathering and transportation fees, ad valorem taxes, recompletion costs, workover costs, development costs, net profits cost, and certain abandonment costs net of salvage. The future net income is before the deduction of state and federal income taxes and general administrative overhead, and has not been adjusted for outstanding loans that may exist nor does it include any adjustment for cash on hand or undistributed income.

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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Crescent Energy Company

January 20, 2023

Liquid hydrocarbon reserves account for approximately 74 percent and gas reserves account for 26 percent of total future gross revenue from proved reserves and the "Other" income represents less than 0.2 percent of total future gross revenue from proved reserves.

The discounted future net income shown above was calculated using a discount rate of 10 percent per annum compounded monthly. Future net income was discounted at four other discount rates which were also compounded monthly. These results are shown in summary form as follows.

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| | |
|:---|:---|
|  | Discounted Future Net Income ($M)<br>As of December 31, 2022 |
| Discount Rate<br> Percent | Total<br>Proved |
| &nbsp;&nbsp;&nbsp;&nbsp;5 | $11990897 |
| 15 | $7687645 |
| 20 | $6543864 |
| 25 | $5711550 |

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The results shown above are presented for your information and should not be construed as our estimate of fair market value.

***Reserves Included in This Report***

The proved reserves included herein conform to the definition as set forth in the Securities and Exchange Commission's Regulations Part 210.4-10(a). An abridged version of the SEC reserves definitions from 210.4-10(a) entitled "PETROLEUM RESERVES DEFINITIONS" is included as an attachment to this report.

The various reserves status categories are defined in the attachment entitled "PETROLEUM RESERVES STATUS DEFINITIONS AND GUIDELINES" in this report. The proved developed non-producing reserves included herein consist of the shut-in, behind pipe status categories.

This report includes an adjustment for a gas imbalance of 2,414 MMcf owed to other parties in the Madden shallow area in Wyoming. No other attempt was made to quantify or otherwise account for any accumulated gas production imbalances that may exist. The proved gas volumes presented herein do not include volumes of gas consumed in operations as reserves.

Reserves are "estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations." All reserves estimates involve an assessment of the uncertainty relating the likelihood that the actual remaining quantities recovered will be greater or less than the estimated quantities determined as of the date the estimate is made. The uncertainty depends primarily on the amount of reliable geologic and engineering data available at the time of the estimate and the interpretation of these data. The relative degree of uncertainty may be conveyed by placing reserves into one of two principal categories, either proved or unproved. Unproved reserves are less certain to be recovered than proved reserves and may be further sub-categorized as probable and possible reserves to denote progressively increasing uncertainty in their recoverability. At Crescent's request, this report addresses only the proved reserves attributable to the properties evaluated herein.

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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Crescent Energy Company

January 20, 2023

Proved oil and gas reserves are "those quantities of oil and gas which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward." The proved reserves included herein were estimated using deterministic methods. The SEC has defined reasonable certainty for proved reserves, when based on deterministic methods, as a "high degree of confidence that the quantities will be recovered."

Proved reserves estimates will generally be revised only as additional geologic or engineering data become available or as economic conditions change. For proved reserves, the SEC states that "as changes due to increased availability of geoscience (geological, geophysical, and geochemical), engineering, and economic data are made to the estimated ultimate recovery (EUR) with time, reasonably certain EUR is much more likely to increase or remain constant than to decrease." Moreover, estimates of proved reserves may be revised as a result of future operations, effects of regulation by governmental agencies or geopolitical or economic risks. Therefore, the proved reserves included in this report are estimates only and should not be construed as being exact quantities, and if recovered, the revenues therefrom, and the actual costs related thereto, could be more or less than the estimated amounts.

Crescent's operations may be subject to various levels of governmental controls and regulations. These controls and regulations may include, but may not be limited to, matters relating to land tenure and leasing**,** the legal rights to produce hydrocarbons, drilling and production practices, environmental protection, marketing and pricing policies, royalties, various taxes and levies including income tax and are subject to change from time to time. Such changes in governmental regulations and policies may cause volumes of proved reserves actually recovered and amounts of proved income actually received to differ significantly from the estimated quantities.

The estimates of proved reserves presented herein were based upon a detailed study of the properties in which Crescent owns an interest; however, we have not made any field examination of the properties. No consideration was given in this report to potential environmental liabilities that may exist nor were any costs included for potential liabilities to restore and clean up damages, if any, caused by past operating practices.

***Estimates of Reserves***

The estimation of reserves involves two distinct determinations. The first determination results in the estimation of the quantities of recoverable oil and gas and the second determination results in the estimation of the uncertainty associated with those estimated quantities in accordance with the definitions set forth by the Securities and Exchange Commission's Regulations Part 210.4-10(a). The process of estimating the quantities of recoverable oil and gas reserves relies on the use of certain generally accepted analytical procedures. These analytical procedures fall into three broad categories or methods: (1) performance-based methods, (2) volumetric-based methods and (3) analogy. These methods may be used individually or in combination by the reserves evaluator in the process of estimating the quantities of reserves. Reserves evaluators must select the method or combination of methods which in their professional judgment is most appropriate given the nature and amount of reliable geoscience and engineering data available at the time of the estimate, the established or anticipated performance characteristics of the reservoir being evaluated, and the stage of development or producing maturity of the property.

In many cases, the analysis of the available geoscience and engineering data and the subsequent interpretation of this data may indicate a range of possible outcomes in an estimate, irrespective of the method selected by the evaluator. When a range in the quantity of reserves is identified, the evaluator must determine the uncertainty associated with the incremental quantities of the reserves. If the reserves quantities are estimated using the deterministic incremental approach, the uncertainty for each discrete

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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Crescent Energy Company

January 20, 2023

incremental quantity of the reserves is addressed by the reserves category assigned by the evaluator. Therefore, it is the categorization of reserves quantities as proved, probable and/or possible that addresses the inherent uncertainty in the estimated quantities reported. For proved reserves, uncertainty is defined by the SEC as reasonable certainty wherein the "quantities actually recovered are much more likely to be achieved than not." The SEC states that "probable reserves are those additional reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered." The SEC states that "possible reserves are those additional reserves that are less certain to be recovered than probable reserves and the total quantities ultimately recovered from a project have a low probability of exceeding proved plus probable plus possible reserves." All quantities of reserves within the same reserves category must meet the SEC definitions as noted above.

Estimates of reserves quantities and their associated reserves categories may be revised in the future as additional geoscience or engineering data become available. Furthermore, estimates of reserves quantities and their associated reserves categories may also be revised due to other factors such as changes in economic conditions, results of future operations, effects of regulation by governmental agencies or geopolitical or economic risks as previously noted herein.

The reserves for the properties included herein were estimated by performance methods, the volumetric method, analogy, or a combination of methods. In general, the reserves attributable to producing wells and/or reservoirs were estimated by performance methods or a combination of methods. These performance methods include, but may not be limited to, decline curve analysis which utilized extrapolations of historical production and pressure data available through September 2022 in those cases where such data were considered to be definitive. The data used in these analyses were furnished to Ryder Scott by Crescent or obtained from public data sources and were considered sufficient for the purpose thereof. In certain cases, producing reserves were estimated by the volumetric method, analogy, or a combination of methods. These methods was used where there were inadequate historical performance data to establish a definitive trend and where the use of production performance data as a basis for the estimates was considered to be inappropriate.

The reserves for the properties included herein attributable to the non-producing and the undeveloped status categories were estimated by analogy. The data utilized from the analogues incorporated into our analysis were considered sufficient for the purpose thereof.

The proved producing and undeveloped categories include reserves (producing: 28,421 Mbbl oil and 124 Mbbl condensate; and undeveloped: 4,555 Mbbl) in the Renee asset (Patrick Draw and Salt Creek fields) located in the Powder River Basin in the state of Wyoming that are associated with CO<sub>2</sub> tertiary operations. Reserves for these properties are based on historical performance trends including decline curve analysis and dimensionless curve analysis of cumulative hydrocarbon pore volume injection and recovery.

To estimate economically producible proved oil and gas reserves and related future net cash flows, we consider many factors and assumptions including, but not limited to, the use of reservoir parameters derived from geological, geophysical and engineering data which cannot be measured directly, economic criteria based on current costs and SEC pricing requirements, and forecasts of future production rates. Under the SEC regulations 210.4-10(a)(22)(v) and (26), proved reserves must be anticipated to be economically producible from a given date forward based on existing economic conditions including the prices and costs at which economic producibility from a reservoir is to be determined. While it may reasonably be anticipated that the future prices received for the sale of production and the operating costs and other costs relating to such production may increase or decrease from those under existing economic conditions, such changes were, in accordance with rules adopted by the SEC, omitted from consideration in making this evaluation.

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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Crescent Energy Company

January 20, 2023

Crescent has informed us that they have furnished us all of the material accounts, records, geological and engineering data, and reports and other data required for this investigation. In preparing our forecast of future proved production and income, we have relied upon data furnished by Crescent with respect to property interests owned, production and well tests from examined wells, normal direct costs of operating the wells or leases, other costs such as transportation and/or processing fees, ad valorem and production taxes, recompletion and development costs, development plans, abandonment costs after salvage, product prices based on the SEC regulations, adjustments or differentials to product prices, geological structural and isochore maps, and pressure measurements. Ryder Scott reviewed such factual data for its reasonableness; however, we have not conducted an independent verification of the data furnished by Crescent. We consider the factual data used in this report appropriate and sufficient for the purpose of preparing the estimates of reserves and future net revenues herein.

In summary, we consider the assumptions, data, methods and analytical procedures used in this report appropriate for the purpose hereof, and we have used all such methods and procedures that we consider necessary and appropriate to prepare the estimates of reserves herein. The proved reserves included herein were determined in conformance with the United States Securities and Exchange Commission (SEC) Modernization of Oil and Gas Reporting; Final Rule, including all references to Regulation S-X and Regulation S-K, referred to herein collectively as the "SEC Regulations." In our opinion, the proved reserves presented in this report comply with the definitions, guidelines and disclosure requirements as required by the SEC regulations.

***Future Production Rates***

For wells currently on production, our forecasts of future production rates are based on historical performance data. If no production decline trend has been established, future production rates were held constant until a decline in ability to produce was anticipated. An estimated rate of decline was then applied until depletion of the reserves. If a decline trend has been established, this trend was used as the basis for estimating future production rates.

Test data and other related information were used to estimate the anticipated initial production rates for those wells or locations that are not currently producing. For reserves not yet on production, sales were estimated to commence at an anticipated date furnished by Crescent. Wells or locations that are not currently producing may start producing earlier or later than anticipated in our estimates due to unforeseen factors causing a change in the timing to initiate production. Such factors may include delays due to weather, the availability of rigs, the sequence of drilling, completing and/or recompleting wells and/or constraints set by regulatory bodies.

The future production rates from wells currently on production or wells or locations that are not currently producing may be more or less than estimated because of changes including, but not limited to, reservoir performance, operating conditions related to surface facilities, compression and artificial lift, pipeline capacity and/or operating conditions, producing market demand and/or allowables or other constraints set by regulatory bodies.

***Hydrocarbon Prices***

The hydrocarbon prices used herein are based on SEC price parameters using the average prices during the 12-month period prior to the "as of date" of this report, determined as the unweighted arithmetic averages of the prices in effect on the first-day-of-the-month for each month within such period, unless prices were defined by contractual arrangements. For hydrocarbon products sold under contract, the contract prices, including fixed and determinable escalations, exclusive of inflation adjustments, were used until expiration of the contract. Upon contract expiration, the prices were adjusted to the 12-month unweighted arithmetic average as previously described.

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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Crescent Energy Company

January 20, 2023

Crescent furnished us with the above mentioned average benchmark prices in effect on December 31, 2022. These initial SEC hydrocarbon prices were determined using the 12-month average first-day-of-the-month benchmark prices appropriate to the geographic area where the hydrocarbons are sold. These benchmark prices are prior to the adjustments for differentials as described herein. The table below summarizes the "benchmark prices" and "price reference" used for the geographic area included in the report. In certain geographic areas, the price reference and benchmark prices may be defined by contractual arrangements.

The product prices that were actually used to determine the future gross revenue for each property reflect adjustments to the benchmark prices for gravity, quality, local conditions, and/or distance from market, referred to herein as "differentials." The differentials used in the preparation of this report were furnished to us by Crescent. The differentials furnished to us were accepted as factual data and reviewed by us for their reasonableness; however, we have not conducted an independent verification of the data used by Crescent to determine these differentials.

In addition, the table below summarizes the net volume weighted benchmark prices adjusted for differentials and referred to herein as the "average realized prices." The average realized prices shown in the table below were determined from the total future gross revenue before production taxes and the total net reserves for the geographic area and presented in accordance with SEC disclosure requirements for each of the geographic areas included in the report.

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|:---|:---|:---|:---|:---|
| Geographic Area | Product | Price<br>Reference | Average<br>Benchmark<br>Prices | Average<br>Realized<br>Prices |
|  North America |  |  |  |  |
|  United States | Oil/Condensate | WTI Cushing | $93.67/bbl | $89.84/bbl |
|  United States | NGLs | WTI Cushing | $93.67/bbl | $37.88/bbl |
|  United States | Gas | Henry Hub | $6.358/MMBTU | $5.80/Mcf |

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The effects of derivative instruments designated as price hedges of oil and gas quantities are not reflected in our individual property evaluations.

***Costs***

Operating costs for the leases and wells in this report were furnished by Crescent and are based on the operating expense reports of Crescent and include only those costs directly applicable to the leases or wells. The operating costs include a portion of general and administrative costs allocated directly to the leases and wells. For operated properties, the operating costs include an appropriate level of corporate general administrative and overhead costs. The operating costs for non-operated properties include the COPAS overhead costs that are allocated directly to the leases and wells under terms of operating agreements. The operating costs furnished to us were accepted as factual data and reviewed by us for their reasonableness; however, we have not conducted an independent verification of the operating cost data used by Crescent. No deduction was made for loan repayments, interest expenses, or exploration and development prepayments that were not charged directly to the leases or wells.

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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Crescent Energy Company

January 20, 2023

Development costs were furnished to us by Crescent and are based on authorizations for expenditure for the proposed work or actual costs for similar projects. The development costs furnished to us were accepted as factual data and reviewed by us for their reasonableness; however, we have not conducted an independent verification of these costs. The estimated net cost of abandonment after salvage was included for properties where abandonment costs net of salvage were material. The estimates of the net abandonment costs furnished by Crescent were accepted without independent verification.

The proved developed shut-in, behind pipe and undeveloped reserves in this report have been incorporated herein in accordance with Crescent's plans to develop these reserves as of December 31, 2022. The implementation of Crescent's development plans as presented to us and incorporated herein is subject to the approval process adopted by Crescent's management. As the result of our inquiries during the course of preparing this report, Crescent has informed us that the development activities included herein have been subjected to and received the internal approvals required by Crescent's management at the appropriate local, regional and/or corporate level. In addition to the internal approvals as noted, certain development activities may still be subject to specific partner AFE processes, Joint Operating Agreement (JOA) requirements or other administrative approvals external to Crescent. Crescent has provided written documentation supporting their commitment to proceed with the development activities as presented to us**.** Additionally, Crescent has informed us that they are not aware of any legal, regulatory, or political obstacles that would significantly alter their plans. While these plans could change from those under existing economic conditions as of December 31, 2022, such changes were, in accordance with rules adopted by the SEC, omitted from consideration in making this evaluation.

Current costs used by Crescent were held constant throughout the life of the properties.

***Standards of Independence and Professional Qualification***

Ryder Scott is an independent petroleum engineering consulting firm that has been providing petroleum consulting services throughout the world since 1937. Ryder Scott is employee-owned and maintains offices in Houston, Texas; Denver, Colorado; and Calgary, Alberta, Canada. We have approximately eighty engineers and geoscientists on our permanent staff. By virtue of the size of our firm and the large number of clients for which we provide services, no single client or job represents a material portion of our annual revenue. We do not serve as officers or directors of any privately-owned or publicly-traded oil and gas company and are separate and independent from the operating and investment decision-making process of our clients. This allows us to bring the highest level of independence and objectivity to each engagement for our services.

Ryder Scott actively participates in industry-related professional societies and organizes an annual public forum focused on the subject of reserves evaluations and SEC regulations. Many of our staff have authored or co-authored technical papers on the subject of reserves related topics. We encourage our staff to maintain and enhance their professional skills by actively participating in ongoing continuing education.

Prior to becoming an officer of the Company, Ryder Scott requires that staff engineers and geoscientists receive professional accreditation in the form of a registered or certified professional engineer's license or a registered or certified professional geoscientist's license, or the equivalent thereof, from an appropriate governmental authority or a recognized self-regulating professional organization. Regulating agencies require that, in order to maintain active status, a certain amount of continuing education hours be completed annually, including an hour of ethics training. Ryder Scott fully supports this technical and ethics training with our internal requirement mentioned above.

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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Crescent Energy Company

January 20, 2023

We are independent petroleum engineers with respect to Crescent Energy Company. Neither we nor any of our employees have any financial interest in the subject properties and neither the employment to do this work nor the compensation is contingent on our estimates of reserves for the properties which were reviewed.

The results of this study, presented herein, are based on technical analyses conducted by teams of geoscientists and engineers from Ryder Scott. The professional qualifications of the undersigned, the technical persons primarily responsible for overseeing, reviewing and approving the evaluation of the reserves information discussed in this report, are included as an attachment to this letter.

***Terms of Usage***

The results of our third party study, presented in report form herein, were prepared in accordance with the disclosure requirements set forth in the SEC regulations and intended for public disclosure as an exhibit in filings made with the SEC by Crescent.

Crescent makes periodic filings on Form 10-K with the SEC under the 1934 Exchange Act. Furthermore, Crescent has certain registration statements filed with the SEC under the 1933 Securities Act into which certain subsequently filed reports are incorporated by reference. We consent to the incorporation by reference in the registration statements on Form S-3 and Form S-8 of Crescent, of the references to our name, as well as to the references to our third party report for Crescent, which appears in certain reports filed by Crescent. Our written consent for such use is included as a separate exhibit to the filings made with the SEC by Crescent.

We have provided Crescent with a digital version of the original signed copy of this report letter. In the event there are any differences between the digital version included in filings made by Crescent and the original signed report letter, the original signed report letter shall control and supersede the digital version.

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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Crescent Energy Company

January 20, 2023

The data and work papers used in the preparation of this report are available for examination by authorized parties in our offices. Please contact us if we can be of further service.

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|:---|:---|:---|
|  | Very truly yours, |  |
|  | **RYDER SCOTT COMPANY, L.P.** |  |
|  | TBPELS Firm Registration No. F-1580 |  |
|  | /s/ Larry P. Connor, P.E.<br> Larry P. Connor, P.E.<br> TBPELS License No. 58639<br> Executive Vice President | ![LOGO](g452425dsp021a.jpg) |
| ![LOGO](g452425dsp011c.jpg) | /s/ Stephen E. Garner, P.E.<br> Stephen E. Garner, P.E.<br> TBPELS License No. 100578<br> Managing Senior Vice President |  |
|  | /s/ Timothy W. Smith, P.E.<br> Timothy W. Smith, P.E.<br> TBPELS License No. 70195<br> Managing Senior Vice President | ![LOGO](g452425dsp011b.jpg) |

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LPC-SEG-TWS (FWZ)/pl

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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**Professional Qualifications of Primary Technical Person** 

The conclusions presented in this report are the result of technical analysis conducted by teams of geoscientists and engineers from Ryder Scott Company, L.P. Larry Connor was the primary technical person responsible for preparing the estimate of the reserves and future production included in this report.

Mr. Connor, an employee of Ryder Scott Company, L.P. (Ryder Scott) since 1981, is the Executive Vice President and is responsible for coordinating and supervising staff and consulting engineers of the company in ongoing reservoir evaluation studies worldwide. Before joining Ryder Scott, Mr. Connor served in a number of engineering positions with Amoco Production Company. For more information regarding Mr. Connor's geographic and job specific experience, please refer to the Ryder Scott Company website at <u>www.ryderscott.com/Company/Employees</u>.

Mr. Connor earned a Bachelor of Science degree in Industrial Engineering from Texas A&M University in 1977 and is a licensed Professional Engineer in the State of Texas, and the Provinces of Alberta, British Columbia and Saskatchewan, Canada. He is also a member of the Society of Petroleum Engineers and the Society of Petroleum Evaluation Engineers. Mr. Connor has served as the Chairman of the Houston Chapter of the Society of Petroleum Evaluation Engineers.

In addition to gaining experience and competency through prior work experience, the Texas Board of Professional Engineers requires a minimum of fifteen hours of continuing education annually, including at least one hour in the area of professional ethics, which Mr. Connor fulfills. Mr. Connor attended an additional 21 hours of formalized in-house training during 2022 covering such topics as the SPE/WPC/AAPG/SPEE Petroleum Resources Management System, reservoir engineering, geoscience and petroleum economics evaluation methods, procedures and software and ethics for consultants. In addition to internal training, Mr. Connor has participated in a total of 6 hours of industry training to professionals outside of Ryder Scott. Mr. Connor has served as course instructor for the formalized in-house training of PSA programming using PHDWinTM software to analyze prospect evaluations.

Based on his educational background, professional training and more than 44 years of practical experience in the estimation and evaluation of petroleum reserves, Mr. Connor has attained the professional qualifications as a Reserves Estimator and Reserves Auditor set forth in Article III of the "Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information" promulgated by the Society of Petroleum Engineers as of June 2019.

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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**Professional Qualifications of Primary Technical Person** 

The conclusions presented in this report are the result of technical analysis conducted by teams of geoscientists and engineers from Ryder Scott Company, L.P. Mr. Stephen E. Gardner is the primary technical person responsible for the estimate of the reserves, future production and income.

Mr. Gardner, an employee of Ryder Scott Company, L.P. (Ryder Scott) since 2006, is a Managing Senior Vice President responsible for ongoing reservoir evaluation studies worldwide. Before joining Ryder Scott, Mr. Gardner served in a number of engineering positions with Exxon Mobil Corporation. For more information regarding Mr. Gardner's geographic and job specific experience, please refer to the Ryder Scott Company website at https://ryderscott.com/employees/denver-employees.

Mr. Gardner earned a Bachelor of Science degree in Mechanical Engineering from Brigham Young University in 2001 (summa cum laude). He is a licensed Professional Engineer in the States of Colorado and Texas. Mr. Gardner is a member of the Society of Petroleum Engineers and a former chairperson of the Society of Petroleum Evaluation Engineers for the Denver Chapter. He also currently serves on the latter organization's board of directors at the international level.

In addition to gaining experience and competency through prior work experience, the Texas Board of Professional Engineers requires a minimum of 15 hours of continuing education annually, including at least one hour in the area of professional ethics, which Mr. Gardner fulfills. As part of his 2022 continuing education hours, Mr. Gardner participated in the annual Ryder Scott Reserves Conference, which covered a variety of reserves topics including analysis techniques for unconventional reservoirs, ESG issues, reserves definitions and guidelines, SEC comment letter trends, and others. In addition, Mr. Gardner attended the annual SPEE meeting held in Napa Valley, California as well as participated in various local SPEE and SIPES technical seminars and other internal company training courses throughout the year covering topics such as reserves evaluation methods and evaluation software, ethics, SEC perspectives and other regulatory issues, geothermal energy, SRMS, and more.

Based on his educational background, professional training and more than 17 years of practical experience in the estimation and evaluation of petroleum reserves, Mr. Gardner has attained the professional qualifications as a Reserves Estimator set forth in Article III of the "Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information" promulgated by the Society of Petroleum Engineers as of June 2019.

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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**Professional Qualifications of Primary Technical Person** 

The conclusions presented in this report are the result of technical analysis conducted by teams of geoscientists and engineers from Ryder Scott Company, L.P. Timothy Wayne Smith was the primary technical person responsible for overseeing the estimate of the reserves, future production and income.

Mr. Smith, an employee of Ryder Scott Company, L.P. (Ryder Scott) since 2008, is a Managing Senior Vice President responsible for coordinating and supervising staff and consulting engineers of the company in ongoing reservoir evaluation studies worldwide. Before joining Ryder Scott, Mr. Smith served in a number of engineering positions with Wintershall Energy and Cities Service Oil Company. For more information regarding Mr. Smith's geographic and job specific experience, please refer to the Ryder Scott Company website at <u>www.ryderscott.com/Employees</u>.

Mr. Smith earned a Bachelor of Science degree in Petroleum Engineering from West Virginia University in 1977 and a Masters of Business (MBA) from the University of Phoenix in 1991 and is a registered Professional Engineer in the State of Texas. He is also a member of the Society of Petroleum Engineers and the Society of Petroleum Evaluation Engineers.

In addition to gaining experience and competency through prior work experience, the Texas Board of Professional Engineers requires a minimum of fifteen hours of continuing education annually, including at least one hour in the area of professional ethics, which Mr. Smith fulfills. Mr. Smith has received extensive training relating to the definitions and disclosure guidelines contained in the United States Securities and Exchange Commission Title 17, Code of Federal Regulations, Modernization of Oil and Gas Reporting, Final Rule released January 14, 2009 in the Federal Register. Mr. Smith has also served as a training instructor for clients regarding Dynamic Analysis and Unconventional Resources. Mr. Smith attended an additional 22 hours of formalized in-house training in the 2022 time period including a course on SPEE Monograph 4 relating to Production Forecasting for Unconventional Reservoirs. Based on his educational background, professional training and over 30 years of practical experience in the estimation and evaluation of petroleum reserves, Mr. Smith has attained the professional qualifications as a Reserves Estimator and Reserves Auditor set forth in Article III of the "Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information" promulgated by the Society of Petroleum Engineers as of June 2019.

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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**PETROLEUM RESERVES DEFINITIONS** 

**As Adapted From:** 

**RULE 4-10(a) of REGULATION S-X PART 210** 

**UNITED STATES SECURITIES AND EXCHANGE COMMISSION (SEC)** 

***PREAMBLE***

On January 14, 2009, the United States Securities and Exchange Commission (SEC) published the "Modernization of Oil and Gas Reporting; Final Rule" in the Federal Register of National Archives and Records Administration (NARA). The "Modernization of Oil and Gas Reporting; Final Rule" includes revisions and additions to the definition section in Rule 4-10 of Regulation S-X, revisions and additions to the oil and gas reporting requirements in Regulation S-K, and amends and codifies Industry Guide 2 in Regulation S-K. The "Modernization of Oil and Gas Reporting; Final Rule", including all references to Regulation S-X and Regulation S-K, shall be referred to herein collectively as the "SEC regulations". The SEC regulations take effect for all filings made with the United States Securities and Exchange Commission as of December 31, 2009, or after January 1, 2010. Reference should be made to the full text under Title 17, Code of Federal Regulations, Regulation S-X Part 210, Rule 4-10(a) for the complete definitions (direct passages excerpted in part or wholly from the aforementioned SEC document are denoted in italics herein).

*Reserves are estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations.* All reserve estimates involve an assessment of the uncertainty relating the likelihood that the actual remaining quantities recovered will be greater or less than the estimated quantities determined as of the date the estimate is made. The uncertainty depends primarily on the amount of reliable geologic and engineering data available at the time of the estimate and the interpretation of these data. The relative degree of uncertainty may be conveyed by placing reserves into one of two principal categories, either proved or unproved. Unproved reserves are less certain to be recovered than proved reserves and may be further sub-categorized as probable and possible reserves to denote progressively increasing uncertainty in their recoverability. Under the SEC regulations as of December 31, 2009, or after January 1, 2010, a company may optionally disclose estimated quantities of probable or possible oil and gas reserves in documents publicly filed with the SEC. The SEC regulations continue to prohibit disclosure of estimates of oil and gas resources other than reserves and any estimated values of such resources in any document publicly filed with the SEC unless such information is required to be disclosed in the document by foreign or state law as noted in §229.1202 Instruction to Item 1202.

Reserves estimates will generally be revised only as additional geologic or engineering data become available or as economic conditions change.

Reserves may be attributed to either natural energy or improved recovery methods. Improved recovery methods include all methods for supplementing natural energy or altering natural forces in the reservoir to increase ultimate recovery. Examples of such methods are pressure maintenance, natural gas cycling, waterflooding, thermal methods, chemical flooding, and the use of miscible and immiscible displacement fluids. Other improved recovery methods may be developed in the future as petroleum technology continues to evolve.

Reserves may be attributed to either conventional or unconventional petroleum accumulations. Petroleum accumulations are considered as either conventional or unconventional based on the nature of their in-place characteristics, extraction method applied, or degree of processing prior to sale. Examples of unconventional petroleum accumulations include coalbed or coalseam methane (CBM/CSM), basin-centered gas, shale gas, gas hydrates, natural bitumen and oil shale deposits. These unconventional accumulations may require specialized extraction technology and/or significant processing prior to sale.

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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PETROLEUM RESERVES DEFINITIONS

Reserves do not include quantities of petroleum being held in inventory.

Because of the differences in uncertainty, caution should be exercised when aggregating quantities of petroleum from different reserves categories.

**<u>RESERVES (SEC DEFINITIONS)</u>**

Securities and Exchange Commission Regulation S-X §210.4-10(a)(26) defines reserves as follows:

***Reserves.*** *Reserves are estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. In addition, there must exist, or there must be a reasonable expectation that there will exist, the legal right to produce or a revenue interest in the production, installed means of delivering oil and gas or related substances to market, and all permits and financing required to implement the project.* 

*<u>Note to paragraph (a)(26):</u> Reserves should not be assigned to adjacent reservoirs isolated by major, potentially sealing, faults until those reservoirs are penetrated and evaluated as economically producible. Reserves should not be assigned to areas that are clearly separated from a known accumulation by a non-productive reservoir (<u>i.e.</u>, absence of reservoir, structurally low reservoir, or negative test results). Such areas may contain prospective resources (<u>i.e.</u>, potentially recoverable resources from undiscovered accumulations).* 

**<u>PROVED RESERVES (SEC DEFINITIONS)</u>**

Securities and Exchange Commission Regulation S-X §210.4-10(a)(22) defines proved oil and gas reserves as follows:

***Proved oil and gas reserves.*** *Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(i) The area of the reservoir considered as proved includes:* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(A) The area identified by drilling and limited by fluid contacts, if any, and* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(B) Adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data.* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(ii) In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons (LKH) as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty.* 

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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PETROLEUM RESERVES DEFINITIONS

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(iii) Where direct observation from well penetrations has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty.* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(iv) Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when:* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(A) Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(B) The project has been approved for development by all necessary parties and entities, including governmental entities.* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(v) Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.* 

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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**PETROLEUM RESERVES STATUS DEFINITIONS AND GUIDELINES** 

**As Adapted From:** 

**RULE 4-10(a) of REGULATION S-X PART 210** 

**UNITED STATES SECURITIES AND EXCHANGE COMMISSION (SEC)** 

**and** 

**2018 PETROLEUM RESOURCES MANAGEMENT SYSTEM (SPE-PRMS)** 

**Sponsored and Approved by:** 

**SOCIETY OF PETROLEUM ENGINEERS (SPE)** 

**WORLD PETROLEUM COUNCIL (WPC)** 

**AMERICAN ASSOCIATION OF PETROLEUM GEOLOGISTS (AAPG)** 

**SOCIETY OF PETROLEUM EVALUATION ENGINEERS (SPEE)** 

**SOCIETY OF EXPLORATION GEOPHYSICISTS (SEG)** 

**SOCIETY OF PETROPHYSICISTS AND WELL LOG ANALYSTS (SPWLA)** 

**EUROPEAN ASSOCIATION OF GEOSCIENTISTS & ENGINEERS (EAGE)** 

Reserves status categories define the development and producing status of wells and reservoirs. Reference should be made to Title 17, Code of Federal Regulations, Regulation S-X Part 210, Rule 4-10(a) and the SPE-PRMS as the following reserves status definitions are based on excerpts from the original documents (direct passages excerpted from the aforementioned SEC and SPE-PRMS documents are denoted in italics herein).

**<u>DEVELOPED RESERVES (SEC DEFINITIONS)</u>**

Securities and Exchange Commission Regulation S-X §210.4-10(a)(6) defines developed oil and gas reserves as follows:

*Developed oil and gas reserves are reserves of any category that can be expected to be recovered:* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(i) Through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well; and* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(ii) Through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the extraction is by means not involving a well.* 

**<u>Developed Producing (SPE-PRMS Definitions)</u>**

While not a requirement for disclosure under the SEC regulations, developed oil and gas reserves may be further sub-classified according to the guidance contained in the SPE-PRMS as Producing or Non-Producing.

***<u>Developed Producing Reserves</u>***

*Developed Producing Reserves are expected quantities to be recovered from completion intervals that are open and producing at the effective date of the estimate.* 

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS

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PETROLEUM RESERVES STATUS DEFINITIONS AND GUIDELINES

*Improved recovery reserves are considered producing only after the improved recovery project is in operation.* 

***<u>Developed Non-Producing</u>***

*Developed Non-Producing Reserves include shut-in and behind-pipe Reserves.* 

***<u>Shut-In</u>***

*Shut-in Reserves are expected to be recovered from:* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(1)* *completion intervals that are open at the time of the estimate but which have not yet started producing;* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(2)* *wells which were shut-in for market conditions or pipeline connections; or* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(3)* *wells not capable of production for mechanical reasons.* 

***<u>Behind-Pipe</u>***

*Behind-pipe Reserves are expected to be recovered from zones in existing wells that will require additional completion work or future re-completion before start of production with minor cost to access these reserves.* 

*In all cases, production can be initiated or restored with relatively low expenditure compared to the cost of drilling a new well.* 

**<u>UNDEVELOPED RESERVES (SEC DEFINITIONS)</u>** 

Securities and Exchange Commission Regulation S-X §210.4-10(a)(31) defines undeveloped oil and gas reserves as follows:

*Undeveloped oil and gas reserves are reserves of any category that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion.* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(i) Reserves on undrilled acreage shall be limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances.* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(ii) Undrilled locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances, justify a longer time.* 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;*(iii) Under no circumstances shall estimates for undeveloped reserves be attributable to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir, as defined in paragraph (a)(2) of this section, or by other evidence using reliable technology establishing reasonable certainty.* 

RYDER SCOTT COMPANY PETROLEUM CONSULTANTS