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FINANCIAL AND OPERATIONAL SUPPLEMENT NOTICE TO INVESTORS Certain statements in this earnings supplement contain "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the


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SLIDE 1

FINANCIAL AND OPERATIONAL SUPPLEMENT

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SLIDE 2

NOTICE TO INVESTORS

Certain statements in this earnings supplement contain "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934 including, without limitation, expectations, beliefs, plans and objectives regarding anticipated financial and operating results, asset divestitures, estimated reserves, drilling locations, capital expenditures, price estimates, typical well results and well profiles, type curve, and production and operating expense guidance included in this earnings supplement. Any matters that are not historical facts are forward looking and, accordingly, involve estimates, assumptions, risks and uncertainties, including, without limitation, risks, uncertainties and other factors discussed in

  • ur most recently filed Annual Report on Form 10-K, recently filed Quarterly Reports on Form 10-Q, recently filed Current Reports on Form 8-K available on our website, www.apachecorp.com,

and in our other public filings and press releases. These forward-looking statements are based on Apache Corporation’s (Apache) current expectations, estimates and projections about the company, its industry, its management’s beliefs, and certain assumptions made by management. No assurance can be given that such expectations, estimates, or projections will prove to have been correct. A number of factors could cause actual results to differ materially from the projections, anticipated results, or other expectations expressed in this earnings supplement, including, Apache’s ability to meet its production targets, successfully manage its capital expenditures and to complete, test, and produce the wells and prospects identified in this earnings supplement, to successfully plan, secure necessary government approvals, finance, build, and operate the necessary infrastructure, and to achieve its production and budget expectations on its projects. Whenever possible, these “forward-looking statements” are identified by words such as “expects,” “believes,” “anticipates,” “projects,” “guidance,” “outlook,” and similar phrases. Because such statements involve risks and uncertainties, Apache’s actual results and performance may differ materially from the results expressed or implied by such forward-looking statements. Given these risks and uncertainties, you are cautioned not to place undue reliance on such forward-looking statements, which speak only as of the date hereof. Unless legally required, we assume no duty to update these statements as of any future date. However, you should review carefully reports and documents that Apache files periodically with the Securities and Exchange Commission. Cautionary Note to Investors: The United States Securities and Exchange Commission (SEC) permits oil and gas companies, in their filings with the SEC, to disclose only proved, probable, and possible reserves that meet the SEC's definitions for such terms. Apache may use certain terms in this earnings supplement, such as “resource,” “resource potential,” “net resource potential,” “potential resource,” “resource base,” “identified resources,” “potential net recoverable,” “potential reserves,” “unbooked resources,” “economic resources,” “net resources,” “undeveloped resource,” “net risked resources,” “inventory,” “upside,” and other similar terms that the SEC guidelines strictly prohibit Apache from including in filings with the SEC. Such terms do not take into account the certainty of resource recovery, which is contingent on exploration success, technical improvements in drilling access, commerciality, and other factors, and are therefore not indicative of expected future resource recovery and should not be relied upon. Investors are urged to consider carefully the disclosure in Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2015 (and Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2016 when filed), available from Apache at www.apachecorp.com or by writing Apache at: 2000 Post Oak Blvd., Suite 100, Houston, Texas 77056 (Attn: Corporate Secretary). You can also obtain this report from the SEC by calling 1-800-SEC-0330 or from the SEC's website at www.sec.gov. Certain information may be provided in this earnings supplement that includes financial measurements that are not required by, or presented in accordance with, generally accepted accounting principles (GAAP). These non-GAAP measures should not be considered as alternatives to GAAP measures, such as net income or net cash provided by operating activities, and may be calculated differently from, and therefore may not be comparable to, similarly titled measures used at other companies. For a reconciliation to the most directly comparable GAAP financial measures, please refer to Apache’s fourth quarter 2016 earnings release at www.apachecorp.com and “Non-GAAP Reconciliations” of this earnings supplement. None of the information contained in this document has been audited by any independent auditor. This earnings supplement is prepared as a convenience for securities analysts and investors and may be useful as a reference tool. Apache may elect to modify the format or discontinue publication at any time, without notice to securities analysts or investors.

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SLIDE 3

TABLE OF CONTENTS

Fourth-Quarter 2016 Financial and Operational Results…………………………… 5 Fourth-Quarter 2016 Regional Summary………………………………………………….. 12 2017/2018 Capital and Production Outlook……………………………………………. 20 Other 2017 Guidance……………………………………………………………………………….. 29 Non-GAAP Reconciliations…….………………………………………………………………….. 34

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SLIDE 4

4Q16 FINANCIAL AND OPERATIONAL RESULTS

4

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SLIDE 5

 Reported Production  Adjusted Production(1)  Oil and Gas Capital Investment(2)

Net Cash From Operating Activities

 Adjusted EBITDAX(2)  Earnings Per Share  Adjusted Earnings Per Share(2,3)

FOURTH-QUARTER 2016 KEY METRICS

490 Mboe/d 421 Mboe/d $537 Million $796 Million $878 Million ($0.48) ($0.06)

(1) Excludes tax barrels, noncontrolling interest in Egypt and divestitures. (2) For a reconciliation to the most directly comparable GAAP financial measure please refer to the appendix. (3) Includes $0.07 per share of dry hole expense.

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SLIDE 6

PRODUCTION AND REVENUES BY PRODUCT

4Q 2016

Reported Production 490 MBOE/D Oil and Gas Revenue $1.46 Billion

Note: Reported volumes include noncontrolling interest and tax barrels in Egypt.

Oil Natural Gas NGLs

77%

Oil Revenue

53%

Oil Production

6

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SLIDE 7

24 45

100 200 300 400 500 600 4Q 2016 Reported Production Egypt Tax Barrels Noncontrolling interest 4Q 2016 Adjusted Production

ADJUSTED PRODUCTION RECONCILIATION

4Q 2016

(1) Excludes tax barrels associated with noncontrolling interest. (1)

North American Onshore Volumes International & Offshore Volumes

490 421

7

Mboe/d

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SLIDE 8

$0.00 $5.00 $10.00 $15.00 $20.00 $25.00 $30.00 $35.00 $40.00 $45.00

Egypt North Sea Permian Other NA

Cash Operating Cost Operating Cash Margin Avg Realization

4Q 2016 OPERATING CASH MARGINS

$37 / Boe $9 / Boe

$28

Per Boe

$31

Per Boe

$20

Per Boe

$22 / Boe $10 / Boe

(1) Operating cash margins calculated as price realizations less lease operating expenses, gathering and transportation costs and taxes other than income.

$12

Per Boe

(1)

Egypt North Sea Permian Other NA

$42 / Boe $11 / Boe $31 / Boe $11 / Boe

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SLIDE 9

$7,492 $7,167 $454 $12 $95 $667 $152 $60 $7

$0 $1,000 $2,000 $3,000 $4,000 $5,000 $6,000 $7,000 $8,000 $9,000 Net Debt 09/30/16 E&P and GTP Cash Spend Leasehold & Property Acquisitions Dividends Cash Flow Changes in Operating Assets and Liabilities Asset Sales Other Net Debt 12/31/16

4Q 2016 NET DEBT RECONCILIATION

(1) For a reconciliation to the most directly comparable GAAP financial measure please refer to the appendix. (2) Net cash provided by operating activities before changes in operating assets and liabilities. For a reconciliation to the most directly comparable GAAP financial measure please refer to the appendix.

(2)

($ in millions)

(1) (1)

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SLIDE 10

OIL AND GAS CAPITAL INVESTMENT

4Q16 (1)

YTD 2016 (1)

E&P and GTP Investment: Permian ................................................................................................ $ 333 $ 906 MidCon / Gulf Coast ................................................................................................ 22 99 Canada ................................................................................................ 33 89 N.A. Onshore ................................................................................................ 388 1,094 Gulf of Mexico ................................................................................................ 16 59 Other (2) ................................................................................................

  • (11)

North America ................................................................................................ 404 1,142 Egypt (Apache's interest only) (3) ................................................................ 58 318 North Sea ................................................................................................ 71 403 Other ................................................................................................ 4 18 Total $ 537 $ 1,881

(In millions)

10

(1) Fourth quarter and YTD 2016 adjustments to total Costs Incurred and GTP Capital Investments:

  • Includes cash plug and abandonment of $22 million and $57 million, respectively.
  • Excludes non-cash plug and abandonment of $(292) million and $(192) million, respectively.
  • For a reconciliation to the most directly comparable GAAP financial measure please refer to the appendix.

(2) YTD 2016 includes an $11M incentive credit for prior year new venture drilling. (3) Fourth quarter and YTD 2016 excludes noncontrolling interest share in Egypt of $26 million and $159 million, respectively.

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SLIDE 11

FOURTH-QUARTER 2016 REGIONAL SUMMARY

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SLIDE 12

FOURTH-QUARTER 2016 GLOBAL OPERATIONS

GLOBAL KEY STATS

Reported Production: 490,376 Boe/d

Drilled & Completed Wells*: 29 gross, 27 net

Rigs: Avg 18 rigs

N.A. ONSHORE KEY STATS

Reported Production: 252,326 Boe/d

Drilled & Completed Wells*: 17 gross, 16 net

Rigs: Avg 8 rigs

INTERNATIONAL & GOM KEY STATS

Reported Production: 238,050 Boe/d

Drilled & Completed Wells*: 12 gross, 11 net

Rigs: Avg 10 rigs

* Includes operated wells completed but not necessarily placed onto production.

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SLIDE 13

Midland Basin

  • Currently running four rigs at Alpine High.
  • Delineation drilling has confirmed an extensive play fairway and over-

pressured regime across Apache’s Alpine High acreage position.

  • Drilling further confirmed hydrocarbon column and Woodford productivity

in southern portion of the play; a second landing zone in the Woodford formation, and productivity in the Pennsylvanian formation.

  • Initial phase of midstream infrastructure on schedule for first pipeline

connection in mid-2017.

  • Announced five new test results on Feb. 14, 2017.

PERMIAN: 4Q 2016 REGION SUMMARY

PERMIAN KEY STATS

FOURTH-QUARTER 2016

Reported Production: 149,302 Boe/d

Drilled & Completed Wells*: 17 gross, 16 net

Rigs: Avg 7 rigs 25 50 75 100 125 150 175 200 Net Production Mboe/d 1Q’15 2Q 3Q 4Q 1Q 2Q 3Q

  • Currently running five primary rig lines and two frac crews.
  • Activity focused on development pad drilling of the Wolfcamp and

Spraberry shale formations in the Wildfire, Azalea and Powell fields.

  • Achieved significant well delivery improvement in 2016, with recent wells
  • utperforming peer type curves.

Delaware Basin / Alpine High

*Operated wells completed but not necessarily placed onto production.

4Q’16

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SLIDE 14

MIDLAND BASIN WELL PERFORMANCE

Recent Wells Outperforming Peer Type Curves

30 60 90 120 150 180 210 Mboe Days on Production APA (5 Wells) Peer A Type Curve 1.2 MMboe EUR Peer B Type Curve 1.0 MMboe EUR

Wolfcamp(1)

(1) Normalized to 7,500' Lateral Length. (2) Includes three previously disclosed wells (Connell 38B 2HM, Connell 38C 2HM, CC 4144E 2HM) and two new wells (Lynch A 6HM & CC 4045W A 1HM).

200 150 100 50

(2)

Lower Spraberry(1)

200 150 100 50 30 60 90 120 150 180 210 Mboe Days on Production APA (3 Wells) Peer A Type Curve 990 Mboe EUR Peer B Type Curve 1,000 Mboe EUR 14

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SLIDE 15

4Q 2016 NORTH AMERICAN ONSHORE WELL RECAP

Well Name Formation Area County Lateral Average 30-Day IP Avg 30-Day IP / 1,000 Lateral Ft % Oil 60-Day Cum-Oil, MBO

DELAWARE BASIN

Blue Jay Unit 101H 3rd Bone Spring Pecos Bend Loving 3,703’ 1,208 Boe/d 326 63% N/A Blue Jay Unit 102H 3rd Bone Spring Pecos Bend Loving 4,865’ 1,379 Boe/d 283 63% N/A Magpie Unit 111H 3rd Bone Spring Pecos Bend Loving 5,936’ 1,084 Boe/d 183 62% 33.5

MIDLAND BASIN

CC 4045 W A # 01HM Wolfcamp B Powell-Miller Upton 10,466’ 2,105 Boe/d 201 80% 87.6 Lynch A HZ # 06HM Wolfcamp B Wildfire Midland 8,277’ 1,598 Boe/d 193 78% 59.9 Lynch A HZ # 02HS

  • L. Spraberry

Wildfire Midland 7,485’ 1,448 Boe/d 193 88% 65.0 Lynch A HZ # 11HS

  • L. Spraberry

Wildfire Midland 7,788’ 1,152 Boe/d 148 86% 49.3 Lynch A HZ # 12HS

  • L. Spraberry

Wildfire Midland 7,635’ 1,252 Boe/d 164 86% 54.6 Lynch A HZ # 17HS

  • M. Spraberry

Wildfire Midland 8,182’ 1,010 Boe/d 123 88% 31.0

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SLIDE 16
  • Completed field-wide 3D seismic survey for use in 4D applications to

high grade drilling locations and build inventory.

  • Operating one platform rig at Forties.

NORTH SEA: 4Q 2016 SUMMARY

NORTH SEA KEY STATS

FOURTH-QUARTER 2016

Reported Production: 69,830 Boe/d

Drilled & Completed Wells*: 2 gross, 2 net

Rigs: Avg 3 rigs

Beryl Area Forties Field

  • Callater subsea tieback under construction and on schedule for first

production delivery in 3Q17.

  • Operating one platform rig at Beryl.

Region Activity

  • 4Q16 production returned to more normalized levels.
  • Contracted to sell non-core, non-producing processing and

transportation assets with sale expected to close 3Q17 following regulatory review.

  • Renegotiated contracts for supply vessels and helicopter services at

lower rates for improved LOE.

  • Operating two semi-submersible drilling rigs under rig share

agreements with another operator.

40 50 60 70 80 Net Production Mboe/d 1Q’15 2Q 3Q 4Q 1Q 2Q 3Q

*Operated wells completed but not necessarily placed onto production.

4Q’16

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SLIDE 17

EGYPT: 4Q 2016 SUMMARY

EGYPT KEY STATS

FOURTH-QUARTER 2016

Reported Production: 159,971 Boe/d

Drilled & Completed Wells*: 10 gross, 9 net

Rigs: Avg 7 rigs

  • Gross production of 345 Mboe/d was down slightly from 3Q16.
  • Adjusted production volumes declined from previous quarter by

approximately 8 Mboe/d, resulting primarily from the impact of improving Brent oil prices on the cost recovery mechanisms in production sharing contracts.

Production Results

20 40 60 80 100 120 Adjusted Production Mboe/d(1) 1Q’15 2Q 3Q 4Q 1Q 2Q 3Q

  • Placed 10 wells on production during 4Q16. The region achieved an

89% drilling success rate for the full-year 2016.

  • Awarded two concessions in November comprising nearly 1.6 million
  • acres. These blocks offset existing Apache acreage with production

and infrastructure. Contracts are expected to be signed mid-2017.

  • Apache will initiate a large, continuous 3-D seismic survey program

to support exploration on the new concessions and development on

  • ur existing acreage.

Region Activity

(1) Excludes tax barrels and noncontrolling interest

*Operated wells completed but not necessarily placed onto production.

4Q’16

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EGYPT: PRODUCTION DETAIL

Mboe/d

2015 2016 1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q

Gross Production 344 349 362 352 353 350 350 345 Net Production 162 185 165 103(1) 166 175 180 160 Adjusted Production 92 95 97 102 103 101 98 90 Brent Oil Benchmark Pricing $55 $64 $51 $45 $33 $45 $47 $49

3Q 2016 4Q 2016 Liquids (Bbls/d) Gas (Mcf/d) Boe/d Liquids (Bbls/d) Gas (Mcf/d) Boe/d

Gross Production 212,608 826,548 350,366 207,541 821,993 344,540 Net Production 111,933 405,863 179,575 100,531 356,637 159,971 % Gross 53% 49% 51% 48% 43% 46% Less: Tax Barrels 24,798 50,753 33,255 18,950 32,121 24,304 Net Production Excluding Tax Barrels 87,135 355,110 146,320 81,581 324,516 135,667 % Gross 41% 43% 42% 39% 39% 39% Less: Noncontrolling Interest 29,028 118,370 48,756 27,194 108,172 45,222 Adjusted Production 58,107 236,740 97,564 54,387 216,344 90,445 % Gross 27% 29% 28% 26% 26% 26%

(1) Includes the impact of a negative tax barrel adjustment.

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SLIDE 19

2017/2018 CAPITAL AND PRODUCTION OUTLOOK

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SLIDE 20

2017 CAPITAL PRIORITIES

Permian Focused Investment

  • 5+ rig program in Midland Basin

 Increase activity with incremental cash flows

  • 4 to 6 rig program at Alpine High
  • Continue Alpine High delineation; initiate
  • ptimization/development
  • Mid-year pipeline connection

Midland/Delaware Egypt & North Sea

  • Invest to sustain long-term FCF
  • Two new concessions in Egypt
  • Callater online 3Q17

Suriname/ Other North America

  • Spud Suriname exploration well late 1Q17
  • Selective investment in other North America

Highlights

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SLIDE 21

Delaware+ Midland Basins 44% CBP & Other Permian 3% Alpine High Midstream 16% International 29% Other North America 8%

APACHE 2017 CAPITAL BUDGET

Note: Capital excludes Egypt noncontrolling interest. (1) Other North America includes Lower 48 (excluding Permian), Canada and Gulf of Mexico. (2) International includes Egypt, North Sea and Suriname.

$3.1 Billion

21

63% of total 2017 oil and gas capital investment allocated to Permian Basin

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SLIDE 22

421 372 425 485 4Q16A 1Q17E 2Q17E 3Q17E 4Q17E 1Q18E 2Q18E 3Q18E 4Q18E 22

APACHE PRODUCTION OUTLOOK

Mboe/d

1H17 Production Impacts:

  • North Sea turnaround
  • Canada gas-plant

maintenance

  • Decline resulting from

reduced 2016 investment

2H17 Growth Drivers:

  • Pipeline connection at Alpine

High

  • Callater start-up
  • Increasing pad completions in

Midland Basin 384 537 455

Note: Adjusted production.

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SLIDE 23

INTERNATIONAL PRODUCTION OUTLOOK

Mboe/d

160 136 154 146 4Q16A 1Q17E 2Q17E 3Q17E 4Q17E 1Q18E 2Q18E 3Q18E 4Q18E 141 164 158 23 Relatively Flat Production Profile

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SLIDE 24

NORTH AMERICA PRODUCTION OUTLOOK

Mboe/d

261 236 271 339 4Q16A 1Q17E 2Q17E 3Q17E 4Q17E 1Q18E 2Q18E 3Q18E 4Q18E 243 291 379 24

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SLIDE 25

MIDLAND/DELAWARE PRODUCTION OUTLOOK

Mboe/d

87 88 125 200 4Q16A 1Q17E 2Q17E 3Q17E 4Q17E 1Q18E 2Q18E 3Q18E 4Q18E 91 135 230 25

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MIDLAND/DELAWARE OIL PRODUCTION OUTLOOK

Mbbls/d

42 43 47 55 4Q16A 1Q17E 2Q17E 3Q17E 4Q17E 1Q18E 2Q18E 3Q18E 4Q18E 44 51 63 26

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APACHE PRODUCTION BY REGION

Midland/Delaware to Drive Apache Growth

Note: Based on Adjusted Production. (1) Other North America Includes Mid-Continent (excluding Permian), Canada and Gulf of Mexico.

4Q16 4Q18

Delaware+Midland Basins 21% CBP & Other Permian 15% Other North America 26% International 38% Midland & Delaware CBP & Other Permian Other North America International

~55%

Permian

36%

Permian

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OTHER 2017 GUIDANCE

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Daily Production (MBOE/D) 2017 Guidance Range Reported Production North America.................................................................................. 252

  • 263

International...................................................................................... 234

  • 243

Total Production............................................................................ 486

  • 506

Adjusted Production North America.................................................................................. 252

  • 263

International (As Reported)................................................................ 234

  • 243

Less: Egypt Tax Barrels................................................................. 45

  • 46

Less: Egypt Noncontrolling Interest.............................................. 43

  • 45

Total Adjusted Production.............................................................. 398

  • 415

Capital Expenditures ($ in millions)* North America................................................................................ $2,200 International.................................................................................... $900 Total ............................................................................................ $3,100

APACHE 2017 GUIDANCE

Production & Capital

29

* Excludes noncontrolling interest.

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APACHE 2017 GUIDANCE

Other Income Statement Items

30

Other Income Statement Items 2017 Guidance Range Operating Costs Lease Operating Expenses ($ per BOE)......................................... $8.50

  • $9.00

Gathering and Transportation ($ in millions)..................................... $200

  • $250

General and Administrative Expenses ($ in millions)........................... $450 Net Interest Expense ($ in millions)................................................... $400 Exploration Expense ($ in millions)*.................................................. $150 DD&A ($ per BOE)........................................................................ $14.00 Cash Taxes ($ in millions)................................................................ $125

* Excludes dry hole and unproved leasehold impairments.

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SLIDE 31

31

2016 PEER OUTSPEND

$ in millions

Source: Company filings. Note: Data as of 2/22/17. (1) 2016 cash flow from operations less capex and dividends paid. Includes Anadarko Petroleum, ConocoPhillips, Devon Energy, Hess, Marathon Oil, Murphy Oil & Gas, Noble Energy, Occidental Petroleum and Pioneer Natural Resources.

($2,790) ($1,944) ($1,809) ($824) ($575) ($537) ($483) ($280) ($280) $102

Peer A Peer B Peer C Peer D Peer E Peer F Peer G Peer H Peer I APA

Average peer

  • utspend of ~$1bn
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DERIVATIVE AND HEDGING ACTIVITIES

32

Open Commodity Derivative Positions as of February 22, 2017

Instrument Index Period Volume (Bbls/d) Strike Put Option WTI July - December 2017 92,000 $50.00 Put Option Platts Dated Brent July - December 2017 83,000 $51.00

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SLIDE 33

NON-GAAP RECONCILIATIONS

33

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SLIDE 34

For the Quarter Ended December 31, 2016 Before Tax After Diluted Tax Impact Tax EPS Income (Loss) Attributable to Common Stock (GAAP) $ (153) $ (29) $ (182) (0.48) Adjustments: * Asset impairments 144 (54) 90 0.23 Valuation allowance and other tax adjustments

  • 69

69 0.18 Discontinued operations

  • Transaction, reorganization & separation costs

3 (2) 1 0.01 Contract termination charges

  • Loss on extinguishment of debt

1

  • 1
  • (Gain) / loss on divestitures

(1)

  • (1)
  • Adjusted Earnings (Non-GAAP)

$ (6) $ (16) $ (22) (0.06)

NON-GAAP RECONCILIATION

Adjusted Earnings

Reconciliation of income attributable to common stock to adjusted earnings Our earnings supplement of adjusted earnings and adjusted earnings per share are non-GAAP measures because they exclude the effect of certain items included in Income Attributable to Common Stock. Management believes that adjusted earnings and adjusted earnings per share provides relevant and useful information, which is widely used by analysts, investors and competitors in our industry as well as by our management in assessing the Company’s operational trends and comparability of results to our peers. Management uses adjusted earnings and adjusted earnings per share to evaluate our operating and financial performance because it eliminates the impact of certain items that management does not consider to be representative of the Company’s on-going business operations. As a performance measure, adjusted earnings may be useful to investors in facilitating comparisons to others in the Company’s industry because certain items can vary substantially in the oil and gas industry from company to company depending upon accounting methods, book value of assets, capital structure and asset sales and other divestitures, among other factors. Management believes excluding these items facilitates investors and analysts in evaluating and comparing the underlying operating and financial performance of our business from period to period by eliminating differences caused by the existence and timing of certain expense and income items that would not otherwise be apparent on a GAAP basis. However, our earnings supplement of adjusted earnings and adjusted earnings per share may not be comparable to similar measures of other companies in our industry.

* The income tax effect of the reconciling items are calculated based on the statutory rate of the jurisdiction in which the discrete item resides.

($ in millions, except per share data)

34

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SLIDE 35

For the Quarter For the Year Ended December 31, Ended December 31, 2016 2015 2016 2015 Net cash provided by continuing operating activities 819 $ 174 $ 2,453 $ 2,554 $ Adjustments: Exploration expense, excluding dry hole expense and unproved leasehold impairments 33 54 120 176 Current income tax provision (benefit) 107 (143) 391 435 Other adjustments to reconcile net loss to net cash provided by operating activities (38) 73 (164) (7) Changes in operating assets and liabilities (152) 475 (153) 80 Financing costs, net 106 110 417 511 Transaction, reorganization & separation costs 3 12 39 132 Contract termination charges

  • 3

10 87 Adjusted EBITDAX (Non-GAAP) 878 $ 758 $ 3,113 $ 3,968 $

NON-GAAP RECONCILIATION

Adjusted EBITDAX

Reconciliation of net cash provided by continuing operating activities to adjusted EBITDAX Management believes EBITDAX, or earnings before income tax expense, interest expense, depreciation, amortization and exploration expense is a widely accepted financial indicator, and useful for investors, to assess a company's ability to incur and service debt, fund capital expenditures, and make distributions to shareholders. We define adjusted EBITDAX, a non-GAAP financial measure, as EBITDAX adjusted for certain items presented in the accompanying reconciliation. Management uses adjusted EBITDAX to evaluate

  • ur ability to fund our capital expenditures, debt services and other operational requirements and to compare our results from period to period by eliminating the impact of certain

items that management does not consider to be representative of the Company’s on-going operations. Management also believes adjusted EBITDAX facilitates investors and analysts in evaluating and comparing EBITDAX from period to period by eliminating differences caused by the existence and timing of certain operating expenses that would not

  • therwise be apparent on a GAAP basis. However, our earnings supplement of adjusted EBITDAX may not be comparable to similar measures of other companies in our industry.

($ in millions)

35

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SLIDE 36

For the Quarter For the Year Ended Ended December 31, Ended December 31, 2016 2015 2016 2015 Net cash provided by operating activities (GAAP) 796 $ 174 $ 2,430 $ 2,667 $ Less: Discontinued operations 23

  • 23

(113) Net cash provided by operating activities excluding discontinued operations 819 $ 174 $ 2,453 $ 2,554 $ Changes in operating assets and liabilities (152) 475 (153) 80 Cash flows from continuing operations before changes in

  • perating assets and liabilities

667 $ 649 $ 2,300 $ 2,634 $

NON-GAAP RECONCILIATION

Cash Flow From Operations Before Changes in Operating Assets and Liabilities

($ in millions)

Reconciliation of net cash provided by operating activities to cash flows from continuing operations before changes in operating assets and liabilities Cash flows from continuing operations before changes in operating assets and liabilities is a non-GAAP financial measure. Apache uses it internally and provides the information because management believes it is useful for investors and widely accepted by those following the oil and gas industry as a financial indicator of a company's ability to generate cash to internally fund exploration and development activities, fund dividend programs, and service debt. It is also used by research analysts to value and compare oil and gas exploration and production companies and is frequently included in published research when providing investment recommendations. Cash flows from operations before changes in operating assets and liabilities, therefore, is an additional measure of liquidity but is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating, investing, or financing activities.

36

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SLIDE 37

December 31, September 30, June 30, March 31, 2016 2016 2016 2016 Current debt

  • $

1 $ 1 $ 1 $ Long-term debt 8,544 8,721 8,719 8,718 Total debt 8,544 8,722 8,720 8,719 Cash and cash equivalents 1,377 1,230 1,201 1,004 Net debt 7,167 $ 7,492 $ 7,519 $ 7,715 $

NON-GAAP RECONCILIATION

Net Debt

($ in millions)

Reconciliation of debt to net debt Net debt, or outstanding debt obligations less cash and cash equivalents, is a non-GAAP financial measure. Management uses net debt as a measure of the Company's outstanding debt obligations that would not be readily satisfied by its cash and cash equivalents on hand.

37

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SLIDE 38

NON-GAAP RECONCILIATION

Oil and Gas Capital Investment

38

For the Quarter For the Year Ended December 31, Ended December 31, 2016 2015 2016 2015 Costs Incurred in Oil and Gas Property: Acquisitions Proved 2 $ 36 $ 45 $ 38 $ Unproved 10 84 170 336 Exploration and Development 112 735 1,420 3,875 124 855 1,635 4,249 GTP Capital Investments: GTP Facilities 125 9 156 282 Total Costs Incurred and GTP Capital Investments 249 $ 864 $ 1,791 $ 4,531 $ Reconciliation of Costs Incurred and GTP to Oil and Gas Capital Investment Asset retirement obligations incurred and revisions 292 $ 192 $ Asset retirement obligations settled 22 57 Less noncontrolling interest (26) (159) Total Oil and Gas Capital Investment 537 $ 1,881 $

($ in millions)

Reconciliation of costs incurred and GTP capital investments to Oil and Gas Capital Investment Management believes the presentation of oil and gas capital investments is useful for investors to assess Apache's expenditures related to our oil and gas capital activity. We define oil and gas capital investments as costs incurred for oil and gas activities and GTP activities, adjusted to exclude asset retirement

  • bligations revisions and liabilities incurred, while including amounts paid during the period for abandonment and decommissioning expenditures. Capital

expenditures attributable to a one-third noncontrolling interest in Egypt are also excluded. Management believes this provides a more accurate reflection of Apache's cash expenditures related to oil and gas capital activity and is consistent with how we plan our capital budget.